OM Mar 2013

March 2013

Houston London Paris Stavanger Aberdeen Singapore Moscow Baku Perth Rio de Janeiro Lagos Luanda

World Trends and Technology for Offshore Oil and Gas Operations

For continuous news & analysiswww.offshore-mag.com

Subsea b

oostin

g &

proce

ssin

g post

er

Geosciencetechnologyadvances

Seismic vessel survey

Dual gradient drilling

Coiled tubing

INSID

E:

Contents | Zoom in | Zoom out Search Issue | Next PageFor navigation instructions please click here

Contents | Zoom in | Zoom out Search Issue | Next PageFor navigation instructions please click here

http://www.sembcorpmarine.com.sg

http://www.offshore-mag.com

†Mark of M-I L.L.C

www.miswaco.com/rhadiant

Produce ultra-high temperature wells fasterRHADIANT† ultra-HT non-aqueous drilling fluid system is the industry’s first drilling fluid proven to deliver stable rheological performance at bottomhole static temperatures (BHST)greater than 500°F (260°C).

An operator in the Gulf of Thailand’s ‘Ring of Fire’ used the RHADIANT drilling fluid systemto efficiently drill a high-angle well with a BHST of 432°F (222°C) with zero lost circulation.A total of seven open-hole logging runs were then performed, all with excellent results.

RHADIANTUltra-high temperature

drilling fluid system

qqM

Mq

qM

MqM

THE WORLD’S NEWSSTAND®

Previous Page | Contents | Zoom in | Zoom out | Front Cover | Search Issue | Next Page

qqM

Mq

qM

MqM




http://www.qmags.com



http://www.miswaco.com/rhadiant

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________





http://www.dril-quip.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________________





http://www.brederoshaw.com

International Edition

Volume 73, Number 3

March 2013

C O N T E N T S

Offshore (ISSN 0030-0608) is published 12 times a year, monthly by PennWell, 1421 S. Sheridan Road, Tulsa, OK 74112. Periodicals class postage paid at Tulsa, OK, and additional offices. Copyright 2013 by PennWell. (Registered in U.S. Patent Trademark Office.) All rights reserved. Permission, however, is granted for libraries and others registered with the Copyright Clearance Center, Inc. (CCC), 222 Rosewood Drive, Danvers, MA 01923, Phone (508) 750-8400, Fax (508) 750-4744 to photocopy articles for a base fee of $1 per copy of the article plus 35¢ per page. Payment should be sent directly to the CCC. Requests for bulk orders should be addressed to the Editor. Subscription prices: US $101.00 per year, Canada/Mexico $ 132.00 per year, All other countries $167.00 per year (Airmail delivery: $234.00). Worldwide digital subscriptions: $101 per year. Single copy sales: US $10.00 per issue, Canada/Mexico $12.00 per issue, All other coun-tries $14.00 per issue (Airmail delivery: $22.00. Single copy digital sales: $8 worldwide. Return Undeliverable Canadian Addresses to: P.O. Box 122, Niagara Falls, ON L2E 6S4. Back issues are available upon request. POSTMASTER send form 3579 to Offshore, P.O. Box 3200, Northbrook, IL 60065-3200. To receive this magazine in digital format, go to www.omeda.com/os.

Celebrating Over 50 Years of Trends, Tools, and Technology

GEOLOGY & GEOPHYSICS

Seismic survey vessel capabilities

go up while count goes down .................................................32

The 2013 tally of seismic vessels worldwide is 142, down eight from

2012. This decrease in number is offset partially by the addition of new,

high-capacity vessels capable of conducting a variety of surveys from

2D through 4D.

Worldwide seismic vessel survey ...........................................34

Get the latest detailed and comprehensive listing of the capabilities and

features of the worldwide seismic vessel fl eet.

Drillers seek a downhole source

for seismic while drilling .........................................................40

Technology International is working with an industry consortium

to develop a wireline-deployed reverse vertical seismic profi ling tool

with extended range and frequencies that can be controlled from the

surface. Also, Schlumberger’s Neil Kelsall discusses the challenges of

bringing SWD offshore.

DRILLING & COMPLETION

Reviewing newbuild drill rig strategies ..................................44

Drilling contractors maintain a portfolio of rigs specifi c to their busi-

ness strategy and their access to capital markets. This second of a

three-part series describes how fi rms specialize and examines their

newbuild strategies. Constructing a newbuild rig is a high-risk invest-

ment, and contractors undertake various strategies to reduce this risk.

Subsea rotating device enhances

dual gradient drilling ...............................................................48

Dual gradient drilling is set to turn the page on a problem that has long

challenged the deepwater industry. By diverting mud returns from

the well immediately above the BOP, sizing the cuttings, and pumping

everything to the surface and a specially confi gured rig, Chevron’s new

DGD system removes a major constraint to drilling at current depths

and points the way to deeper waters and more challenging reservoirs.

32

48

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.omeda.com/os

Setting the StandardMarine Seismic Acquisition

A N Y W H E R E . A N Y T I M E . E V E R Y T I M E .

Ahead of the CurveSM

Sentinel, Nautilus & Seal 428

offer the most advanced streamer

solution for optimum marine seismic recording.

Sentinel® : THE BEST-IN-CLASS STREAMER PERFORMANCE� ��

Nautilus® : THE MOST EFFICIENT STREAMER GUIDANCE� ��

Seal 428 : THE NEW-GENERATION MARINE SEISMIC RECORDER� ��!"�� #��$��

Nantes, [email protected]

Houston, [email protected]

www.sercel.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.sercel.com

Tactical Technology™

gets high-integrity casing string to total depth

weatherford.com

Our Tactical Technology does not end

there. Find out how we integrate our broad

portfolio with cross-discipline expertise

to get high-integrity casing strings to TD.

Contact your Weatherford representative or

visit weatherford.com/TotalDepth.

International Edition

Volume 73, Number 3

March 2013

D E P A R T M E N T S

PRODUCTION OPERATIONS

Enhanced coiled tubing improves

well intervention offshore Malaysia .......................................................................... 52

Fiber optic-enabled coiled tubing is a real-time bottomhole measurement and communication

system that uses live telemetry to read bottomhole measurements. As opposed to the conven-

tional coiled tubing string, where job parameters are read from the surface, fi ber optic-enabled

coiled tubing improves job effi ciency by removing the guesswork concerning downhole

behavior.

SUBSEA

Novel deepwater riser bundle is constructed offshore ............................................. 58

Together with Total and INTECSEA, Heerema Marine Contractors is developing a new offshore

constructed hybrid riser bundle installed using heavy-lift and pipelay vessels.

Subsea processing comes of age .............................................................................. 64

While an increase in overall recovery is the primary reward of subsea processing, there are also

inherent benefi ts associated with the development and implementation of new technologies.

This atmosphere fosters increased competition, which in turn drives innovation.

COVER: While the num-

ber of seismic survey vessels

has fallen, service companies

have been busy expanding and

enhancing their capabilities of

the remaining fl eet, including a

number of new, high-capacity

vessels capable of conducting

a variety of surveys from 2D

through 4D. The WG Columbus

(cover) is one of the many 3D

vessels in the WesternGeco

marine seismic acquisition fl eet.

It is shown here deploying the

company’s proprietary Q-Marine

solid steamers while participat-

ing in multiclient surveys in the

Gulf of Mexico. (Photo courtesy

of WesternGeco)

Online .................................................... 8

Comment ............................................. 10

Data ..................................................... 12

Global E&P .......................................... 14

Offshore Europe .................................. 18

Gulf of Mexico ..................................... 20

Subsea Systems ................................. 22

Vessels, Rigs, & Surface Systems ...... 24

Drilling & Production .......................... 26

Geosciences ........................................ 28

Offshore Automation Solutions .......... 30

Business Briefs ................................... 72

Advertisers’ Index ............................... 75

Beyond the Horizon ............................ 76

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



OverDrive™ casing running and

drilling systems combine many

conventional casing tools into

one system; and extends

the functionality of the rig’s

top drive from drillpipe

to casing, enabling

simultaneous rotation,

reciprocation/push-

down and circulation of

the casing string.

Drilling-with-casing (DwC™)

systems can drill, run, set and

cement casing in a single trip. DwC

technology eliminates the risks of

tripping pipe and BHAs and protects

against drilling hazards with casing in

the hole all the way to total depth (TD).

Performance-matched Technology

Our Tactical Technology can be employed

in virtually any drilling environment.

��

TorkDrive™ tool, the OverDrive system

enhances safety and wellbore integrity and

reduces nonproductive time. Our Defyer™

series of drillable casing bits provide high

penetration rates and durability in a wide

variety of formation types and compression

strengths. The new Defyer DPA drillable

casing bit makes DwC operations possible

in deeper, harder formations at longer

intervals than ever before.

___________________





http://www.weatherford.com

http://www.weatherford.com/TotalDepth

weatherford.com

Well construction

• Cementing products

• Drilling tools

• Drilling-with-casing systems

• ��

• Integrated drilling rigs

• Liner systems

• Mechanized rig systems

• Rig equipment sales

• ��

• ��

• ��

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



Drilling

Evaluation

Completion

Production

Intervention

© 2

01

3 W

eath

erfo

rd. A

ll righ

ts r

eser

ved.

Inco

rpor

ates

pro

prie

tary

and

pat

ente

d W

eath

erfo

rd t

echn

olog

y.

Reach Total DepthWeatherford’s Total Depth

SM

services combine engineering expertise with performance-matched technology to help reach planned your target.

��

��

��Total Depth��

Total Technology™��!��total team��total track record"#��

��#��

��#��#��$��

Offshore California, USA�%��™��

��&'�&((� ��)*�+,'��-�

��

Oman %��#��)�#.™-��

OverDrive��

��

��#��)/�-�

��#��Total Depth ��0��

.�� weatherford.com/TotalDepth�__________________





http://www.weatherford.com

http://www.weatherford.com/TotalDepth

PennWell1455 West Loop South, Suite 400, Houston, TX 77027 U.S.A.

Tel: (01) 713 621-9720 • Fax: (01) 713 963-6296

SALES

WORLDWIDE SALES MANAGERHOUSTON AREA SALES

David Davis [email protected] Tel: (713) 963-6206Mitch Duffy [email protected]

CUSTOM PUBLISHINGRoy Markum [email protected]

Tel: (713) 963-6220

PRODUCTION MANAGERKimberlee Smith [email protected]: (918) 832-9252 • Fax: (918) 831-9415

REPRINT SALESRhonda Brown [email protected]

Tel: (219) 878-6094 • Fax: (219) 561-2023

SUBSCRIBER SERVICE

Contact subscriber service for subscription questions, address changes and back issues

Tel: (847) 559-7501 • Fax: (847) 291-4816

Email: [email protected]

OFFSHORE EVENTS

David Paganie (Houston) [email protected] Killough (Houston) [email protected] Vrettos (London) [email protected]

Jenny Phillips (London) [email protected]

CORPORATE HEADQUARTERS

PennWell; 1421 S. Sheridan Rd., Tulsa, OK 74112 Member

All Rights reservedOffshore ISSN-0030-0608

Printed in the U.S.A. GST No. 126813153CHAIRMAN:

Frank T. Lauinger

PRESIDENT/CHIEF EXECUTIVE OFFICER:Robert F. Biolchini

CHIEF FINANCIAL OFFICER:Mark C. Wilmoth

Publications Mail Agreement Number 40052420

GST No. 126813153

CONTRIBUTING EDITORSF. Jay Schempf (Houston)Dick Ghiselin (Houston)

Doug Gray (Rio de Janeiro)Nick Terdre (London)

Gurdip Singh (Singapore)

TECHNOLOGY EDITOR,SUBSEA & SEISMIC

Gene [email protected]

EDITOR-EUROPEJeremy Beckman

[email protected]

ASSISTANT EDITORJessica Tippee

[email protected]

SENIORTECHNICAL EDITOR

Russell [email protected]

POSTER EDITORE. Kurt Albaugh, P.E.

[email protected]

PRESENTATION EDITORJosh Troutman

[email protected]

VICE PRESIDENT and GROUP PUBLISHERMark Peters

[email protected]

MANAGING EDITORBruce A. Beaubouef

[email protected]

CHIEF EDITOR/CONFERENCE EDITORIAL DIRECTORDavid Paganie

[email protected]

®

8 Offshore March 2013 • www.offshore-mag.com

Latest news

The latest news is posted daily for the offshore oil and gas industry coveringgttechnology, companies, personnel moves, and products.

www.offshore-mag.com

New Video

➤ Skarv

BP began production from the Skarv fi eld in the Norwegian Sea in De-ccember 2012. Development is based around a 295 m (968 ft) long, 51 m (167 fft) wide turret-moored FPSO with 875,000-bbl storage capacity, connected to 113 risers and ultimately receiving production from 16 wells connected to fi ve ssubsea drilling templates.

New On Demand Webcasts

➤ Geohazard prediction in deepwater wells

In high-pressure/high-temperature environments, the lateral extent, struc-ttural position and architecture of the reservoirs become much more critical to tthe viability of a prospect, and also determine the range of safe depths where aa specifi c reservoir can be penetrated without the risk of a pressure infl ux. Dr. AAlan R. Huffman, chief technology offi cer of SIGMA³ Integrated Reservoir SSolutions, discusses how the accurate prediction of the reservoir pressures at aa specifi c penetration point can be the difference between an effi ciently man-aaged drilling operation and a potentially catastrophic pressure infl ux event.

http://www.offshore-mag.com/webcasts/offshore/2013/02/

geohazard-prediction-in-deepwater-wells.html

Technical Digests

➤ Advances in subsea recovery

Subsea processing technologies enable offshore fi elds to reach their full po-ttential. They are a proven solution for accelerating production and increasing rrecovery from hard-to-access offshore reserves. FMC Technologies is leading tthe way with the development and supply of subsea processing technologies ssuch as separation, boosting, and compression.

http://www.offshore-mag.com/technical-digests/2012/08/fmc.html

New maps, posters, & surveys

• 2013 Marine Seismic Vessel Survey • 2013 Top 10 Drilling Contractors • Gulf of Mexico Map• 2013 Deepwater Gulf of Mexico Discoveries

Download: http://www.offshore-mag.com/maps-posters.html

Browse Offshore magazinee

Peruse the cover issue and archives back to 1995.www.offshore-mag.com

Submit an article

Offshore magazine accepts editorial contributions. To submit an article, pplease review the guidelines posted on our website by following the link below..

www.offshore-mag.com/index/about-us/article-submission.html

Available at

Offshore-mag.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________________________






http://www.offshore-mag.com/index/about-us/article-submission.html


http://www.offshore-mag.com/maps-posters.html

http://www.offshore-mag.com/technical-digests/2012/08/fmc.html

http://www.offshore-mag.com/webcasts/offshore/2013/02/geohazard-prediction-in-deepwater-wells.html



At Avondale, our highly skilled workforce is energized and set to deliver innovative solutions

for upstream, midstream and downstream energy infrastructure projects. Backed by our

vast facilities, unmatched capabilities, and 75-year legacy of success, we’re harnessing our

energy to build solutions today that will power the world for years to come.

World-Class Engineering and Modular Construction

for Energy Infrastructure Projects

Visit us at www.hii-avondale.com

504-654-5000 | 5100 River Road Avondale, LA 70094

THEY ALL FLOW THROUGH

AVONDALE

UPSTREAM,MIDSTREAM

ORDOWNSTREAM,

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.hii-avondale.com

• Crawfi sh • Beer and soft drinks

• Barbecue • Hot dogs • Bratwurst

• Live band • Children’s games

• Desserts • Raffl es

Sunday, May 5, 2013 / 1-5 p.m.

$35/ticket ($40 at the door)

University of Houston

(entrance #1 – off Spur 5)

Lynn Eusan Park

TITANIUM SPONSORS

Thank You 2012 Sponsors

For tickets & sponsorship Information:

contact Diane Ashen, (713) 271-1983

• ASHEN & ASSOCIATES WORLDWIDE

EXECUTIVE SEARCH

• RADOIL

• AKER SOLUTIONS

• BAKER HUGHES

• CAMERON

• DRIL-QUIP

• GE OIL & GAS

• PENNWELL

PLATINUM SPONSORS

• EMERSON PROCESS MANAGEMENT

• FMC TECHNOLOGIES

• FORUM ENERGY TECHNOLOGIES

• FREUDENBERG OIL & GAS LLC

• KEY ENERGY SERVICES

• MARATHON OIL

• OCEANEERING

• SCANA OFFSHORE

• SCHLUMBERGER

• STRESS ENGINEERING SERVICES

• TECHNIP

• TEJAS RESEARCH & ENGINEERING

• TESCO CORPORATION

• WEATHERFORD

CORPORATE SPONSORS

• DASS MACHINE OF ARKANSAS

• EXPRESS ENERGY SERVICES

• FORGE USA

• HALLIBURTON

• LOGISTICS INTERNATIONAL

• OIL STATES INDUSTRIES

• TRANSOCEAN

Proceeds go to Engineering Scholarships

ASME/UH

OTCCrawfi sh

Boil

25th Annual

Kickoff Event for the OTC

World’s Largest Crawfi sh Boil


To respond to articles in Offshore, or to offer articles for publication,

contact the editor by email ([email protected]).

C O M M E N T David Paganie • Houston

A modern case of resource nationalismAn apparent shift in thinking is emerging among states from that of maximizing re-

source revenues to maximizing the use of the resource revenue stream for the benefi t of the local economy and to attract foreign investment. A recent report by Wood Mackenzie suggests that, beginning this year, resource nationalism may give way to resource maxi-mization. Governments are reassessing the need for foreign investment in technology, capital, and expertise. Some states may opt to ease their hard line stance on resource na-tionalism, while other states are seeking to solidify their process of managing petroleumrevenue. One example of the latter is Ghana.

Global interest in Ghana’s upstream sector was triggered by the Mahogany-1 discov-ery in 2007, which culminated with fi rst production from Jubilee in 2010. Its emergingpetroleum industry is attracting an increasing share – from $860 million in 2010 to $1.67 billion in 2011 – of regional commodity related foreign direct investments. Increasing oil revenues also helped boost its GDP growth rate to nearly 14% in 2011. Additional phases of Jubilee and subsequent production from TEN (Tweneboa, Enyenra, and Ntomme) should help sustain production and associated revenue for the foreseeable future.

Ghana is seeking to solidify its requisite policies and institutional structures for ef-fective management and oversight of the petroleum sector. One key challenge for the country, according to a recent report by the African Development Bank (ADB), is its preparedness to handle the environmental issues of the sector including the capacity to monitor the environmental impacts of oil production.

The ADB has outlined some of Ghana’s key initiatives. In 2010, Ghana achieved Ex-tractive Industry Transparency Initiative (EITI) compliant status and extended the initia-tive to include the oil and gas sectors. Between 2010 and 2011, Ghana passed several laws governing the management of oil revenues to ensure transparency and accountability. Key bills passed include the Petroleum Revenue Management Act (PRMA) and the Pe-troleum Commission Bills. To meet provisions of the PRMA, the Environmental and Nat-ural Resources Advisory Council (ENRAC), chaired by the vice president, was created.

Established in 2011 by the Petroleum Commission Act, Act 821, and in accordance with Ar-ticle 269 of the 1992 Constitution of Ghana, the Petroleum Commission, Ghana (the Commis-sion) was established to regulate the upstream sector of the Ghanaian petroleum industry.

The Commission took over regulation of the sector from the Minister of Energy, whohitherto regulated the sector with the assistance of Ghana National Petroleum Corpora-tion (GNPC). Indeed, Act 821 specifi cally requires GNPC to cease to exercise any advi-sory function in relation to the regulation and management of the utilization of petroleumresources and the coordination of policies in relation to them six months after the pas-sage of Act 821. This took effect on Jan. 16, 2012.

Establishing the regulatory framework for resource management is a process and Ju-

liette Twumasi‐Anokye, legal advisor, Petroleum Commission of Ghana, will elaborate on the government’s current activities with respect to local content development at the 17th annual Offshore West Africa Conference & Exhibition (OWA), March 19-21, 2013,

International Conference Center, Accra, Ghana. The Commission also will discuss the development of a Common Qualifi cation System aimed at ensuring all companies operating in the upstream sector are registered with the Commission, setting minimum standards for local content plans, evaluation of contracting strategy, and tender pre-qualifi cation.

New legislation to address local content and participation is expected to be presentedto Parliament shortly for deliberation and enactment.

Subsea boosting and processing trends

Currently, subsea processing projects can be found in nearly every major offshore oil and gas region in the world, while most of the activity to date is the North Sea and offshore Brazil (Campos and Espirito Santo basins). Still an emerging market, with the number of installed systems relatively small (about 30), recognition of the potential returns and hence the level of acceptance of subsea processing technologies continues to increase, explains the authors of a report inside this issue on the outlook of subsea boosting and processing systems. The full report begins on page 64, and is accompanied by the 2013 Worldwide Survey of Subsea

Processing Systems poster, which includes a new section on subsea power transmission.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Subsea production systems

Because the seafloor is the new surface

www.akersolutions.com/subsea© Copyright 2012.

All rights reserved. Trade Mark of Aker Solutions and its subsidiaries.

Subsea: just another example of ingenuity delivered by Aker Solutions

Transferring subsea production and processing systems to the seabedhelps operators produce from declining reservoirs at extended depths.

But engineering seabed-based �� reliable over the long term meansnew challenges, and projects of an unprecedented scale and complexity.

No stranger to extreme technical challenges, Aker Solutions’

offshore and deepwater heritage makes us the perfect

subsea partner. Our portfolio includes power umbilicals,

boosting systems, trees, tie-in systems and control

equipment, as well as intervention services - everything it

takes to build, run and maintain a subsea production system.

��

expected to increase recovery by up to 280 million barrels.

When it comes to the next frontier, we’re already working at it.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.akersolutions.com/subsea

Worldwide offshore rig count & utilization rate

February 2011 – January 2013

950

850

750

650

550

450

350

100

90

80

70

60

50

40

No

. o

f ri

gs

Fle

et u

tilizatio

n ra

te %

Feb11

May

11

Aug11

Nov11

Feb12

May

12

Aug12

Nov12

Contracted fleet utilization Total fleet Contracted Working

Sourc

e: IH

S

Mediterranean production additions 2008-2017

1,400,000

1,200,000

1,000,000

800,000

600,000

400,000

200,000

0

Lebanon

Turkey

Tunisia

Spain

Libya

Italy

Cyprus

Croatia

Albania

Israel

Greece

Egypt (Mediterranean)

Source: Infield Systems Ltd.

2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

Pro

du

cti

on

(B

PD

E)

Worldwide day rates

Year/Month Minimum Average Maximum

Drillship

2012 Feb $155,000 $438,955 $674,000

2012 Mar $155,000 $438,533 $671,000

2012 Apr $157,000 $443,150 $671,000

2012 May $157,000 $438,961 $671,000

2012 June $50,000 $433,711 $671,000

2012 July $50,000 $437,808 $671,000

2012 Aug $50,000 $442,438 $671,000

2012 Sept $50,000 $429,559 $671,000

2012 Oct $50,000 $431,149 $674,000

2012 Nov $50,000 $432,983 $674,000

2012 Dec $50,000 $441,325 $674,000

2013 Jan $50,000 $450,176 $674,000

Jackup

2012 Feb $36,000 $107,566 $339,000

2012 Mar $36,000 $107,673 $366,000

2012 Apr $36,000 $107,989 $366,000

2012 May $36,000 $108,450 $366,000

2012 June $36,000 $110,695 $366,000

2012 July $30,000 $111,416 $366,000

2012 Aug $40,000 $111,420 $366,000

2012 Sept $40,000 $111,810 $366,000

2012 Oct $30,000 $112,260 $366,000

2012 Nov $30,000 $114,578 $366,000

2012 Dec $30,000 $115,406 $366,000

2013 Jan $30,000 $118,310 $366,000

Semi

2012 Feb $137,000 $362,730 $655,000

2012 Mar $137,000 $358,313 $655,000

2012 Apr $137,000 $362,083 $655,000

2012 May $125,000 $361,040 $655,000

2012 June $125,000 $359,971 $655,000

2012 July $69,825 $354,127 $675,000

2012 Aug $69,825 $360,661 $675,000

2012 Sept $130,000 $358,776 $675,000

2012 Oct $130,000 $358,444 $655,000

2012 Nov $130,000 $362,568 $655,000

2012 Dec $130,000 $363,881 $655,000

2013 Jan $137,000 $366,291 $655,000

Source: Rigzone.com

G L O B A L D ATA


Infield Systems expects 89 fields – 62 of them to be gas – in the Mediterranean to enter production between 2013 and 2017. Anticipated offshore develop-ment within Israel’s waters is a key talking point in the industry today, with Noble Energy’s Leviathan and Tamar fields expected to enter production before the end of the forecast period. The fields are estimated to hold combined gross mean resources of 26 tcf (736 bcm) of gas. Noble Energy also has enjoyed success on its Aphrodite field offshore Cyprus, with the third largest forecast production additions during the period after Leviathan and Tamar. The Aphrodite field is esti-mated to hold between 3 and 9 tcf (85 and 255 bcm). Infield Systems currently expects the field to enter production before the end of 2017.

Egypt’s Mediterranean waters account for the larg-est share of production across the 2008-2017 period. It is the only country expected to bring onstream new fields in each successive year of the 10-year time-frame. Between 2013 and 2017, Egypt’s Mediterranean

sector is expected to bring an additional 30 fields onstream, with the most significant developments expected to include BP’s Raven gas field, anticipated to be brought onstream via a fixed platform instal-lation during the course of 2015 and its Giza North field, forecast to enter production before the end of 2017 via a subsea satellite development.

Libya is scheduled to bring onstream several fields within the next five years, including the Hess-operated Arous Al Bahar development and Eni’s Libya NC 41 development. Offshore Italy, Infield Systems expects key projects to include Eni’s Panda and Mediterranean Oil and Gas’ Ombrina Mare developments, expected to enter production in 2016 and 2017 respectively.

– Catarina Podevyn, Analyst, Infield Systems Ltd.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








http://www.Rigzone.com

RAISING PERFORMANCE. TOGETHER™

Take a closer look at Cameron. And prepare to look far and wide. That’s

because Cameron is there in more ways than one. We maintain our

global presence to support you in the fi eld. Our breadth of product

covers the full spectrum – from individual components, to systems, to

complete packaged solutions designed to meet customer-specifi c needs

– all while delivering proven reliability and optimum value. Together with

comprehensive aftermarket support, we’re there for the life of your asset. For the solid, industry-

leading solutions partner you seek, look no further. Discover Cameron. www.c-a-m.com

ONSHORE DRILLING

OFFSHORE DRILLING

ONSHORE PRODUCTION

OFFSHORE PRODUCTION

SUBSEA PRODUCTION

TOPSIDES PROCESSING

TRANSMISSION / STORAGE

REFINING / PETROCHEMICAL / LNG

INDUSTRIAL

DISCOVER CAMERON

Upstream to downstream,

onshore to offshore, we’re there.™

1

1

2

2

3

3

4

4

5

5

6

6

7

7

8

8

9

9

CAMERON’S MARKET SEGMENTS

F L O W E Q U I P M E N T L E A D E R S H I P

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.c-a-m.com

G L O B A L E & P Jeremy Beckman • London


Latin America

Pemex has contracted McDermott Inter-national for a new production platform for the Litoral Tabasco Tsimin-Xux fi elds in the Gulf of Mexico. The $230-million PB-Litoral-A contract scope includes construction and installation of a 1,800-metric ton (1,984-ton) jacket and 4,500-metric ton (4,960-ton) top-sides, associated piles, tripods, and bridges. McDermott’s Intermac barge will install the topsides by the fl oatover method. In addi-tion, the company will perform tie-ins and brownfi eld work on the CA-Litoral-A HP compression platform.

•••Karoon Gas Australia has discovered oil

in the Santos basin offshore Brazil’s Santa Catarina coast. The Kangaroo-1 well, drilled in blocks S-M-1101 and S-M-1165, encoun-tered a 25-m (82-ft) gross light oil column in Eocene reservoirs. Pressure data analysis has established an oil/water contact. Karoon aims to drill an appraisal well to target potentially higher volumes at the structure’s crest. The blocks are in 400 m (1,312 ft) of water, south of Rio de Janeiro, and 112 km (69.6 mi) offshore.

•••Brazilian agency ANP has approved the

development plan for the Atlanta postsalt oil fi eld in the Santos basin, operated by QGEP Participaoes. The location is 185 km (115 mi) offshore. The third partner is Barra En-ergia do Brasil.

West Africa

Chevron has become operator of three deepwater concessions offshore Morocco,60-120 mi (100-1200 km) north and west of Agadir. The company will acquire seismicand perform evaluation studies of the Rhir Deep, Cantin Deep, and Cap Walidia Deep areas. Chevron has a 75% interest, in part-nership with state-owned ONHYM.

Cairn Energy has assumed operatorship of Morocco’s offshore Foum Draa block and aims to drill a fi rst exploratory well this fall, if it can secure a rig. The well will target a lower Cretaceous objective.

•••Eni has completed its fi rst appraisal well of

the Sankofa East deepwater oil discovery in the Tano basin offshore Ghana. Sankofa East 2A was drilled in 900 m (2,952 ft) of water in the Offshore Cape Three Points block, 50 km (31 mi) offshore. It encountered gas and con-densate, and oil in Cretaceous sands. Eni now estimates recoverable oil in the structure at 150 MMbbl, and is working on commercial-ization options with partners Vitol and GNPC.

•••Eco (Atlantic) Oil & Gas has signed joint

operating agreements for three licenses off-shore Namibia with Azimuth and state-owned NAMCOR. The Cooper, Guy, and Sharon li-

censes are all in the Walvis basin. Eco views the region as a prospective oil play.

•••Cabinda Gulf Oil Co. (CABGOC) is push-

ing ahead with the Mafumeira Sul develop-ment in Angola’s offshore Cabinda province.The $5.6-billion project is the second-stage program on the Mafumeira fi eld in block O, 15 mi (24 km) offshore and in 200 ft (60 m) of water. It involves fabrication and instal-lation of fi ve new platforms, including two wellhead facilities and a central processing/compression complex; drilling of 50 wells; and laying 75 mi (121 km) of subsea pipe-lines. First oil is slated for 2015, with output building to 110,000 b/d, plus 10,000 b/d of liquid petroleum gas. Associated natural gas will head to the Angola Liquefi ed Natural Gas plant in Soyo.

•••BP has started production from its multi-

fi eld PSVM development in block 31 off-shore Angola. Under the fi rst phase, three wells on the Plutao fi eld should deliver 70,000 b/d of oil. Output should double as more wells come online later this year at the Venus and Saturno fi elds and on Martenext year. A total of 40 oil production, gas and water injection wells will be connected via 15 subsea manifolds to the 1.6-MMbbl storage capacity FPSO. Water depths in this northeast corner of the block reach 2,000 m (6,562 ft). Another hub is planned in the southeast sector.

Mediterranean Sea

Cairn Energy has entered an exploration agreement with Malta’s government. This covers various blocks offshore Malta in the Sicily Channel, extending over a total area of around 6,000 sq km (2,317 sq mi).

•••Two major oil companies have entered

the exploration fray offshore Republic of Cyprus, following successful bids under the country’s second licensing round. Eni was awarded 80% operating interests in blocks 2, 3, and 9 in the Cypriot deep offshore areaof the Levantine basin, in partnership withKogas. Total signed production-sharing con-tracts for blocks 10 and 11 southwest of the island, in water depths ranging from 1,000-2,500 m (3,281-8,202 ft). The company plans to acquire 2D and 3D seismic, and says the blocks contain different play types.

•••Noble Energy expects to start gas pro-

duction from the deepwater Tamar fi eld in the Israeli sector next month. This will be piped to the nearshore platform that was in-stalled late last year, and production will be combined with output from the Mari-B plat-form owned by the Yam Tethys consortium,of which Noble is a member. Later this year

the company may sanction a second phase development of Tamar and a fi rst phase for the giant Leviathan discovery, currently un-dergoing appraisal drilling.

Middle East

Saudi Aramco’s latest jackup should have started operations following delivery fromconstructor Keppel FELS in Singapore. The rig’s jackup legs are more than 400 ft (122 m) long, allowing it to work on the deepest water fi elds offshore Saudi Arabia such as Arabiya, Hasbah, Karan, and Marjan. Other features include a 54-motor jacking system, allowing it to carry a greater load than tra-ditional 36-motor rigs, and a water cooling system for faster heat removal.

Another jackup, built at Lamprell’s Ham-riyah yard in the UAE, has departed for a drilling contract offshore India for ONGC. The Greatdrill Chaaya, built for GreatshipGlobal Energy Services, is a LeTourneauSuper 116E design, with a modifi ed spudcan arrangement to suit the anticipated sea-bed conditions.

•••Dana Gas has struck an accord with the

emirates of Ajman and Sharjah over devel-opment of the Zora gas fi eld, 33 km (20.5 mi) offshore the UAE. Production will come from a single platform linked to onshoreprocessing facilities, and providing gas for power generation in the northern UAE.

East Africa

Rwanda’s Ministry of Natural Resourceshas granted Vanoil Energy a two-month extension for a technical evaluation agree-ment. This will allow the Canadian company to negotiate a production-sharing contract

The jackup Greatdrill Chaaya at Lamprell’s yard.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Jurong Shipyard � Sembawang Shipyard � SMOE � PPL Shipyard � Jurong SMLEstaleiro Jurong Aracruz � Sembmarine Kakinada � Sembmarine SLP

Discover a company where customer loyalty is engraved in stone. Sembcorp Marine has turned marine and offshore construction into an art form. We have a relentless focus on detail, an unyielding commitment to quality and safety, and unparalleled respect for budgets.

As a result our customers come back time after time. Their loyalty is why we built two rigs between 2000 and 2005 and 47 since that time. And that’s why we are growing at a record rate, from a single shipyard in 1963 to nine today. Two new yards, one in Singapore and the other in Brazil, will commence operations soon and position Sembcorp Marine to better serve our customers.

Contact Sembcorp Marine today. We’ll show you why we think marine and offshore construction is not just a science, it’s an art. Discover Sembcorp Marine. [email protected]

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







ON BELCLENE BELCOR BELGARD BELLACIDE BELLASOL BELSPERSE BROMICIDE FLOCON BELCLENE BEL

BELCOR® BELGARD® BELLACIDE® BELLASOL® BELSPERSE® BROMICIDE® FLOCON® BELCLENE® BELCOR® BELGARD®

CIDE® FLOCON® BELCLENE® BELCOR® BELGARD® BELLACIDE® BELLASOL® BELSPERSE® BROMICIDE® FLOCON® BEL-

BELLASOL® BELSPERSE® BROMICIDE® FLOCON® BELCLENE® BELCOR® BELGARD® BELLACIDE® BELLASOL® BELSPERSE®

BWA Water Additives is the global leader

in sustainable water treatment solutions

for topside or down-hole production,

seawater injection or squeeze treatment.

• Bellasol scale inhibitors are environmentally

friendly, high-performance antiscalant polymers.

• New Bellacide 350 – highly effective non-oxidizing

biocide that improves health and safety. Widely used

in hydraulic fracking.

• BWA supports oil and gas service companies

in over 80 countries.

N® BELCLENE® BELELLCCORCORCORORR®®® BELGBELGBELGARRARAR

SPERSE® BBBRBRBROROMICIDE® FLOCON® B

BELLLLLLALALACIDE® BELLASOL® BELSP

G L O B A L E & P

for a 1,631-sq km (630-sq mi) tract of the East Kivu graben, beneath Lake Kivu.

•••Anadarko has awarded the Fluor/JGC

joint venture a front-end engineering design (FEED) contract for an onshore LNG facil-ity in Cabo Delgado province, Mozambique. The location is 2,000 km (1,243 mi) north-east of the capital Maputo. The FEED con-cerns the plant’s fi rst phase for which four trains are planned, each with capacity for 5 MM metric tons/yr of LNG. Feedstock will come from the Anadarko-operated Area 1 deepwater gas discoveries in Mozambique’s portion of the Rovuma basin.

India

ONGC has commissioned a process plat-form for the Heera redevelopment project in the Arabian Sea, 70 km (43 mi) southwest of Mumbai. The $271-million contract for engi-neering, construction, and installation went to a consortium of Technip, AFCONS Infrastruc-ture, and TH Heavy Engineering. Topsides for the new HRD platform will be designed for fl oatover installation using Technip’s Un-ideck method, and the completed facility will be bridge-linked to the existing HRC platform. All work should be fi nished in early 2015.

•••

A tribunal in India has ruled in Hardy Oil and Gas’ favor concerning a request for an extension to a license in the northern Cau-very basin offshore Pondicherry. The CY-OS/2 exploration block includes the 2007 Ganesha-1 gas discovery well. After a long period in limbo, Hardy and its partners nowhave a further three years to perform ap-praisal activities.Asia/Pacifi c

CNOOC has signed production-sharingcontracts with Chevron for blocks 15/10 and 15/28 in the eastern South China Sea. Water depths range from 50-100 m (164-328 ft). Chevron will acquire 3D seismic over both blocks and cover all costs during the exploration phase.

This year CNOOC aims to drill around140 exploration wells on its various inter-ests, and bring onstream 10 new oil and gas fi elds offshore China. These include Liwan 3-1, the country’s fi rst large-scale deepwater gas development.

•••The semisubmersible Ocean General has

discovered oil and gas for Salamander Ener-gy on the South Kecapi structure in Indone-sia’s North Kutei basin. Hydrocarbons were encountered in Pliocene sandstones, with higher well pressures than expected. This

may indicate a highly active hydrocarbon-charging system, the company claimed.

•••Sabah Shell Petroleum has contracted the

Technip/Malaysia Marine and Heavy Engi-neering (MMHE) venture for a TLP for the Malikai deepwater project.

The 26,000-metric ton (28,660-ton) facility’s topsides will be able to process 60,000 b/d of oil and 1.4 MMcf/d (39,644 cm/d) of gas.

Technip will handle engineering of the hull and moorings in Kuala Lumpur and MMHE will build the TLP at its yard in Jo-hor, Malaysia. The tendons will be fabricat-ed at a yard on the US Gulf Coast.

•••Eni and PetroVietnam have agreed to

work together to develop opportunities inVietnam and elsewhere. Eni, which was awarded operatorship last year of three ex-ploration blocks in the Gulf of Tonkin, will gain access to further Vietnamese blocks. PetroVietnam in turn can develop a pres-ence in other countries where Eni has con-cessions, and avail itself of some of Eni’s advanced technologies.

•••INPEX Masala has awarded Wood Group

Kenny a front-end engineering design con-tract for subsea production facilities for the

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



Bellasol® Antiscalants &Bellacide® Biocides

Sustainable Solutions for Severe Service Conditions

Contact us today: [email protected] [email protected] [email protected] [email protected] www.wateradditives.com





http://www.wateradditives.com

KaMOS® Gaskets for sealing and surveillance

Selected references:

BP, ExxonMobil, Total, Saipem, Shell, Hyundai, ConocoPhillips,

Chevron, PTTEP, Halliburton, AMEC Paragon, Technip Offshore UK Ltd

“KaMOS® Gaskets to be used, when having too many leakages in flanged connections...”

KaMOS® Gaskets verifies correct installation by pressure

testing the ring room in flanges.

Time, cost and safety efficient

leakagetest solutions

KaMOS® Kammprofil Gasket

KaMOS® RTJ GasketP.O.Box 484, N-4291 Kopervik, Norway • Tel +47 52 84 43 40 • Fax +47 52 84 43 41 • [email protected] • www.kamos.no

- the efficient solution for flanged connections

G L O B A L E & P

Abadi LNG project. This will involve con-struction of a fl oating LNG plant producing2.5 MM metric tons/yr (2.76 MM tons/yr) from the Abadi gas fi eld in the Arafura Sea offshore Indonesia. PT JGC Indonesia and PT Saipem Indonesia are performing FEED for the FLNG facilities under a design com-petition.

Australasia

Apache and JX Nippon have completed farm-ins to the WA-435 and WA-337-P permits off Western Australia. According to partner Carnarvon Petroleum, which now holds a 20% interest, drilling could start late this year on the multi-tcf gas prospect Phoenix South in Triassic reservoirs, using the Atwood Eagle.Depending on the result, a well may follow on the Roc prospect. The locations are close to the Phoenix-1 gas discovery.

Chevron has notched its 20th gas discov-ery offshore Western Australia since mid-2009. The Kentish Knock South-1 well inter-sected 246 ft (75 m) of net gas pay in upper Mungaroo sands on the WA-365-P permit,173 mi (280 km) north of Exmouth. Waterdepth was 3,832 ft (1,168 m).

•••New Zealand Oil and Gas (NZOG) has

been awarded outright ownership of a new

exploration block in New Zealand’s offshore Taranaki region. Block 12TAR8 off the south coast is north of the company’s Ka-kapo prospect, and appears to be within the

same source kitchen as the producing Maui and Maari offshore oil and gas fi elds. NZOG plans to kick off exploration with a 400-km (248-mi) 2D seismic survey. �

New Zealand Oil and Gas’s newly-awarded offshore acreage.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.kamos.no

O F F S H O R E E U R O P E Jeremy Beckman • London


BP completes Valhall overhaul

BP has fi nally delivered fi rst oil from the Valhall redevelopment in the NorwegianNorth Sea. Start-up was originally sched-uled for the second half of 2010, but a series of delays forced BP to extend operations at facilities that were due to be replaced.

The project, sanctioned in mid-2007, is de-signed to keep the giant Valhall fi eld in ser-vice through 2050. Its original platforms, in-stalled in 1982, had a design life of 15 years. Redevelopment involved commissioning a new production, utilities and accommoda-tion platform built by Heerema, Aker Verdaland SLP, and installed by the Saipem crane barge S700. This has been bridge-linked to the existing Valhall IP water injection plat-form, with Aker Offshore Partner perform-ing associated modifi cations and hookup.

The new platform comprises an 8,400-met-ric ton (9,259-ton) jacket supported by an 18,500-metric ton (20,393-ton) topsides. Ac-cording to analysts ScanBoss, early designs envisaged a single-lift installation offshorefor the topsides, but the fi nal weight ne-cessitated nine separate lifts, including the bridges. Capex for the entire project has risen from the initially approved NOK 14.6 billion ($2.65 billion) to an estimated NOK 16.1 billion ($2.9 billion).

Valhall now has seven manned platformsand two unstaffed fl ank wellhead platforms,where gas-lift has been introduced. BP and partner Hess are also considering develop-ment of the fi eld’s west fl ank via a furtherwellhead facility. Another change is a new 294-km (182-mi) subsea DC cable from Lista on the Norwegian mainland that providespower to the entire Valhall complex. This should cut carbon dioxide (CO2) emissions from the fi eld during the next few years by 300,000 tons/yr ScanBoss says, along with 250 tons/yr of nitrogen oxide.

Hyundai, SMOE clinch

Norway topsides

Far Eastern yards are reapingmuch of the benefi t of Norway’soffshore development surge.Hyundai Heavy Industries in South Korea will build the 21,000-ton top-sides for Statoil’s Aasta Hansteen spar in the Norwegian Sea, having earlier won the contract to build the 195-m (640-ft) tall hull. This will be the world’s largest spar to date, the fi rst to work offshore Europe,and the fi rst to include storage for produced condensate. The top-sides will be designed to process23 MMcmoe/d of light oil and gas, and will be built with the assistance of Houston-based CB&I. Contract value is $1.1 billion.

Sembcorp Marine subsidiary SMOE in Singapore has a letter of intent from Det nor-ske oljeselskap to construct the 13,700-met-ric ton (15,101-ton) Iver Aasen platformtopsides. The process, drilling and quarters platform will be installed in 112 m (367 ft) of water in the central Norwegian North Sea, and will include modules for processing, gas compression, separation, water injection and metering. Production will be sent to the new complex on Lundin’s Edvard Grieg fi eld. SMOE should start work on the $900-million EPC project in December, with sailaway of the topsides scheduled for March 2016.

Some heavy-duty engineering will remainin Europe, with Heerema Fabrication Groupwinning a letter of award for the 16,000-ton steel jacket for Statoil’s North Sea Dagny platform. Assuming sanction for the Dagny development from the Norwegian authori-ties, Heerema should cut fi rst steel on the 142-m (466-ft) high jacket and pre-drillingwellhead deck in November at its yard in Vlissingen, the Netherlands. The jacket will be installed in 116 m (380 ft) of water, andthe completed platform will export gas to the Sleipner facilities, with oil offl oaded toshuttle tankers.

In Norway, Aker Solutions’ base in For-nebu and its plants in Tranby and Egersund will fabricate the subsea trees, template manifolds, and dynamic and steel tube um-bilicals for Aasta Hansteen, at a total cost of $419 million.

EnQuest sees

further life in Thistle

EnQuest has committed to a further ex-tension of production from the Thistle fi eldin the UK northern North Sea. The platformis one of the longest-serving in the UK sec-tor, originally installed by BP, later operated by DNO and subsequently Lundin Britain. When EnQuest acquired Thistle in 2010, it

initiated a facilities overhaul program that included reactivation of the platform’s rig, drilling of fi ve new wells, and upgrades to the safety systems.

Output has increased as a result of these measures, and following the UK government’s introduction of a Brownfi eld Allowances pro-gram, EnQuest is now targeting production of a further 35 MMboe. Next-phase plans include installation of a 30-MW power generation tur-bine, topsides integrity work, and a new pro-cess control safety system. The estimated cost is around $266 million.

In the central UK sector, the company is seeking partner approval for a $200-million program to widen the scope of the Alma/Galia development, which is due to deliver fi rst oil this fall. EnQuest is looking to add swivel capacity to the FPSO, strengthen thevessel’s hull, and upgrade to its mooring sys-tem. The aims are to lengthen the FPSO’s service life and to lift fi rst-phase recovery to34 MMboe. If approved, overall capex would rise to $1.2 billion.

Wintershall fi nds oil

in Norwegian Sea

Wintershall is proving to be one of Nor-way’s most adroit practitioners with the drillbit. Following close on the company’s Asha oil discovery in the Ivar Aasen area,the company has proven gas condensate in the Rodriguez structure in the NorwegianSea, 4 km (2.5 mi) northeast of the Statoil-operated Tyrihans fi eld. The well, drilled by the semisub Transocean Arctic in 291 m (955 ft) of water, encountered hydrocarbons in Lower Cretaceous sandstones in the Lange formation. Partner Faroe Petroleum givesan upper-end estimate for Rodriguez at 126 MMboe, although more appraisal drilling will be needed.

In the same region, Faroe is a partner in RWE Dea’s Fogelberg gas discovery, which

is inching toward a development decision. Timing will likely coin-cide with gas export capacity be-coming available within a few years on the Norwegian pipeline system. The government is considering re-ducing gas transportation tariffs fornew gas fi eld developments, with consultations due to be completed by the middle of this month. A change could improve the econom-ics of both Fogelberg and Rodri-guez, Faroe claims.

The Norwegian Sea accountedfor 14 of the new offshore produc-tion licenses awarded earlier this year under Norway’s 2012 Awards in Pre-Defi ned Areas round. Three more were issued in the BarentsSea and 34 in the North Sea. �The helideck of the EnQuest-operated Thistle platform.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________





http://www.smt.sandvik.com

G U L F O F M E X I C O Bruce Beaubouef • Houston


The semisubmersible hull for Chevron’s Jack/St. Malo project begins its

voyage from Geoje, South Korea, bound for the Kiewit yard in South Texas,

on the Dockwise Vanguard heavy transport vessel. (Courtesy Dockwise)

GoM oil production up in 2012, says EIA

Oil production in the federal Gulf of Mexico waters grew 6% last year, according to a new report issued by the US Energy Informa-tion Administration.

The report, “Short‐Term Energy Outlook Supplement: Key drivers for EIA’s short‐term U.S. crude oil production outlook,” says that oil pro-duction in the federal GoM is projected to have increased from about 1.31 MMb/d in January to about 1.39 MM b/d in December 2012.

The increase was driven by the initiation of production at 13 new deepwater fi elds with a combined peak production of about 195,000 b/d, as well as the restart of the Mad Dog fi eld, which had been of-fl ine since April 2011.

Also contributing to the increase was the start‐up of the Tahiti Phase 2 redevelopment project, as well as those deepwater fi elds that began production in 2011 but continued to increase production during 2012.

EIA expects federal GoM production to increase from an average 1.27 MMb/d in 2012 to an average 1.39 MMb/d in 2013. Much of that increase is the result of new projects that started producing in 2012 but do not reach peak production until late 2012 or early 2013. Adding to federal GoM production in 2013 will be a combination of six new fi eld start‐ups with a combined peak production of about 45,000 b/d, and the Na Kika Phase 3 redevelopment project.

Hess provides Tubular Bells update

Development of the Tubular Bells fi eld is proceeding on schedule, with the drilling campaigns under way and construction of the spar platform ongoing. Project operator Hess Corp. provided an update at Offshore’s Topsides conference recently held in Galveston, Texas.

The drilling program began last year, and the Stena Forth has been on-site since April. To date, it has drilled nine topholes and is currently drill-ing the second well. When the drilling program concludes, the project will have three to fi ve producers, and two to three water injection wells.

Construction of the spar platform is under way in Texas and Loui-siana. The engineering and construction of the project is being con-ducted almost entirely within the United States.

The initial subsea development will comprise two drill centers con-nected to three production wells and two water injection wells. Thereis a possibility that two additional production wells and one additional water injection well may be added to the fi eld development.

The subsea facilities will be tied back to a Williams Partners-owned fl oating production spar (FPS) with a 50-person accommoda-tion capacity. Hess will initially operate the production facility.

The spar platform is designed to handle:• 60,000 b/d of oil

• 135 MMcf/d of gas production• 40,000 bbl produced water treating capacity• 60,000 bbl of water injection per day.Export from the FPS will be through Williams’ existing pipeline

systems, including its 12-in. oil line and its 12-in. natural gas line.First production is planned for the 2Q 2014. The primary target

lies at approximately 24,000 ft (7,315 m) reservoir depth below ap-proximately 10,000 ft (3,048 m) of salt.

The Tubular Bells project was sanctioned in 2011 with Hess hav-ing a 57.14% working interest as operator. Chevron has the remain-ing 42.86% interest.

Central GoM Lease Sale 227

scheduled for March

The US Interior Department and the Bureau of Ocean Energy Man-agement have announced that Central Gulf of Mexico Lease Sale 227 will offer 38.6 million acres offshore Louisiana, Mississippi, and Alabama.

Lease Sale 227 encompasses 7,299 blocks located from 3 (4.8 km)to about 230 mi (370 km) offshore, in water depths ranging from 9 to more than 11,115 ft (3 to 3,400 m). BOEM estimates the sale could result in the production of 460 MMbbl to 890 MMbbl of oil, and 1.9 tcf to 3.9 tcf of natural gas.

The sale is scheduled for March 20, 2013, in New Orleans, and in-cludes all unleased areas in the Central Gulf of Mexico Planning Area. It will be the second such sale under the 2012-2017 OCS leasing program.

The terms of this sale include conditions the BOEM says will ensure both orderly resource development, and protection of the human, marine and coastal environments. These include stipula-tions to protect biologically sensitive resources, mitigate potential adverse effects on protected species, and avoid potential confl ictsassociated with oil and gas development in the region.

Jack/St. Malo hull leaves shipyard

The semisubmersible hull for Chevron’s Jack/St. Malo deepwater Gulf of Mexico project has sailed out of the Samsung Heavy Industries yard in Geoje, South Korea, bound for the Kiewit yard in south Texas.

At 56,000 metric tons (61,730 tons), the hull is the world’s largest to date, said marine contractor Dockwise. The successful fl oat-on opera-tion was the fi rst for the company’s new Dockwise Vanguard heavy trans-port vessel. The hull is scheduled to arrive at the Kiewit yard mid-April.

The Jack and St. Malo fl oating production unit will be installed in 7,000 ft (2,100 m) water depth. The $7.5-billion development will comprise three subsea centers tied back to the FPU with a capacity of 170,000 b/d of oil and 42.5 MMcf/d of natural gas. Startup is planned for 2014. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








8,118

TeleCoilsystem

treatment

Typicalcoiled tubing

treatment

8,200

Actualvolume

area

Conventionalvolume

area

Tubing collars

Tubing collars

Gas lift mandrel

Eliminate ambiguity in coiled tubing operations with the TeleCoil system.With the TeleCoil™ downhole communication system,

you can correlate depths in real time and access

critical differential pressure and temperature data—

reducing risk and uncertainty while ensuring efficient

coiled tubing operations.

Leverage the system’s unparalleled functionality in

applications ranging from mechanical intervention to

stimulation. And by integrating coiled tubing and

logging operations, you’ll simplify wellsite logistics.

Critical operational parameters? Unverified downhole conditions?

© 2

012

Bake

r H

ughe

s In

corp

orat

ed. A

ll Ri

ghts

Res

erve

d. 3

5780

09/

2012

bakerhughes.com/reduceCTuncertainty

During a scale removal

operation on a gas lift mandrel,

TeleCoil system data facilitated

precise fluid placement, reducing

treatment volumes by 50%.

Advancing Reservoir Performance

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.bakerhughes.com/reduceCTuncertainty

S U B S E A S Y S T E M S Gene Kliewer • Houston


Equipment & engineering news

Aker Solutions has signed a contract with Statoil for the supply of deepwater umbilicals to the Aasta Hansteen fi eld on the Norwegiancontinental shelf. The contract value is approximately NOK 280 mil-lion ($51 million). Aker Solutions’ scope of work includes the design, engineering and manufacturing of dynamic and static umbilicals, a riser base, and ancillary equipment. The steel tube umbilicals will be manufactured and delivered out of Aker Solutions’ facility in Moss, Norway, supported by project management, design and engineering in Fornebu, Norway. The umbilical riser base will be manufacturedat Aker Solutions’ facility in Egersund.

Following award of the umbilicals contract, Aker also won the NOK 2-billion ($365-million) contract to supply the subsea produc-tion system, which includes three template-manifold structures,seven subsea trees, in addition to wellheads, controls, workover and tie-in systems. The fi rst deliveries of the Aasta Hansteen subsea pro-duction system will be made in the fi rst half of 2015.

Aasta Hansteen is a deepwater project consisting of the three structures Luva, Haklang, and Snefrid South at a water depth of 1,300 m (4,264 ft). The structures are 140 km (87 mi) north of the nearest existing offshore infrastructure.

The planned fi eld development for Aasta Hansteen includes what would be the fi rst spar on the Norwegian continental shelf.

Subsea 7 S.A. has a contract from Esso Exploration and Produc-tion Nigeria Ltd for the development of the Erha North fi eld offshore Nigeria in water depths of 1,000-1,200 m (3,820-3,936 ft). Subsea 7’s scope of work includes the engineering, procurement, fabrication, and installation of 25 km (15.5 mi) of fl owlines, 15 km (9.3 mi) of um-bilicals, and 17 rigid jumpers. The scope also includes modifi cationsto the FPSO in order to integrate it with the new subsea facilities.

Signifi cant parts of the design will be executed in Nigeria and all subsea structures will be fabricated in Nigeria, says Subsea 7. Off-

shore installation is scheduled to commence in early 2015, using the Seven Borealis and the Seven Pacifi c.

Wood Group Kenny has won an $8.6-million contract by INPEX Masela, Ltd. for front-end engineering and design of major subsea production facilities for the Abadi LNG project in Indonesia. The Abadi project will involve the construction of a fl oating LNG plant, which will produce 2.5 MM metric tons/yr (2.8 MM tons/yr) in the fi rst stage of development.

PT. Wood Group Indonesia, supported by the Wood Group Ken-ny offi ces in Perth and Melbourne, will perform the FEED, which involves a comprehensive engineering workscope for the subsea, umbilical, riser and fl owline (SURF) systems, including subsea structures and equipment. A further FEED contract for the FLNG facilities is expected to be awarded separately. �

UK subsea future growth looks strong

Subsea companies across the UK are set to grow by 20% or more in 2013, with some companies anticipating more than50% growth, according to a survey of members by Subsea UK. The tally has 100% of respondents predicting significantgrowth this year. Almost half expect to grow by 30% and a third by more than 50%.

In 2012, more than half the reporting companies saw growthof 20% and a fifth reporting more than 50% growth.

The key drivers were sustained high oil price, an increase in global demand, and the introduction of new technology tomake more developments viable.

The fastest growing segments were inspection, repair and maintenance, integrity and reliability, decommissioning, andoffshore wind.

The biggest challenge remains recruiting and retainingskilled people, with 88% citing this as their foremost con-straint. Other challenges reported by 15% or more respon-dents were access to finance and working capital, findingsuitable premises, controlling costs, and managing growth.

Around 80% felt that the UK was still the world-leader in subsea but 12% warned that competition was becoming increasingly fierce and other countries like Norway and the United States were challenging that position.

The main international markets for UK subsea companies were given as Norway, Brazil, United States, Southeast Asia, Australia, West Africa, and the Middle East. Respondents wereasked to rank their overseas markets in order of priority. Nor-way came out on top, with 25% of those surveyed indicating it was their first focus over the next few years, followed by theUnited States (24%) and Brazil (20%). Less than 12% said that the UK North Sea was a priority.

NCS Survey has purchased two Teledyne Gavia AUVs. These vehicles,

shown here being deployed, are the latest in the Gavia Offshore Sur-

veyor series and are equipped with high-resolution side scan sonar, a

multi-beam echo sounder, a sub-bottom profiler, an ultra-short baseline

positioning system, long baseline, GPS, and an inertial navigation

system. The AUVs are used to provide ultra-high-resolution data for

pipeline and platform inspections; scour monitoring surveys; cable and

pipe route surveys; and offshore wind farm surveys. The vehicles are

rated to 1,000 m (3,280 ft) but regularly operate in depths as shallow as

2 m (6½ ft). They can perform in currents of more than 2 knots, under

jackup drilling rigs and very close to fixed platform structures. NCS

says no module weighs more than 25 kg (55 lb) in its transit case.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Frank Mohn AS - Oil & GasN-5918 Frekhaug - Norwaytel. +47 55 999 400 - fax. +47 55 999 [email protected] - www.framo.com

Framo Water Injection Pumps

In the international oil and gas industry Frank Mohn AS Oil & Gas are recognised as a leading designer, manufacturer and supplier of complete pumping systems for both onshore and offshore applications.

Keywords are solid craftmanship combined with innovation and world-wide service.

Firewater Pumps Seawater Lift Pumps Water Injection Pumps Crude Offloading Pumps

The high pressure pump is designed to meet

changing reservoir demands. Small footprint,

compact low weight, booster integrated,

running below first critical speed.BOOSTING PRODUCTION

Please visit us at

our stand in the

Norwegian Pavillion

6 - 9 May

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.framo.com

V E S S E L S , R I G S , & S U R FA C E S Y S T E M S Russell McCulley • Houston


Dalian lands Seadrill double

Seadrill has placed a $460-million order with Dalian Shipbuild-ing Industry Offshore for two high-spec jackup rigs, with delivery scheduled for 1Q and 2Q 2015. Based on the Friede & Goldman JU2000E design, the rigs will be capable of operation in water depths up to 400 ft (122 m) and will be able to drill to 30,000 ft (9,144 m). The contract includes options for two additional JU2000E units, which would be delivered in 3Q and 4Q 2015.

Exmar, EDF push plan for US LNG export

EDF Trading and Exmar have announced a joint effort to bring mobile, barge-mounted natural gas liquefaction units to LNG termi-nals in the US for small-scale export opportunities. The units will be modeled on Exmar’s FLRSU project under construction for Pacifi cRubiales in Colombia, which includes a jetty-moored barge outfi t-ted with Black & Veatch’s PRICO liquefaction equipment that will receive gas from the onshore La Creciente fi eld. Like the Pacifi cRubiales project, the proposed North American units will be built by China’s Wison Group. The aim would be to bring mobile, self-contained liquefaction units to LNG import terminals in the US us-ing existing pipeline, tank and jetty infrastructure to enable LNG export, Exmar said.

Ichthys on track for 2016, Inpex says

Japan’s INPEX in late January cut fi rst steel on what it claims will be the world’s largest semisubmersible, a 1.66 MMcf/d capac-ity central processing facility bound for the Ichthys LNG project in the Browse basin offshore Western Australia. Samsung Heavy In-dustries is building the semi at its Geoje shipyard in Korea, with detailed engineering by Mustang. Earlier in January, fi rst steel was cut for the 65-m (213-ft) tall turret for the project’s FPSO unit. SBM Offshore is providing engineering, procurement, fabrication, and supply services for the turret. Inpex and its Ichthys partner Totalexpect fi rst production by the end of 2016.

Mustang, SMOE team on Ivar Aasen topsides

Det norske oljeselskap and its partners in the Ivar Aasen fi eldhave awarded a contract worth NOK 4 billion ($722 million) to Sembcorp Marine subsidiary SMOE for topside facilities at the Ivar Aasen fi eld offshore Norway.

The contract covers engineering, procurement, and constructionof the 13,700-metric ton (15,101-ton) platform deck. The facilities include process, gas compression, separation, water injection, fl are boom, and metering, along with accommodations for 70 people.

Construction is scheduled to begin in December 2013, with deliveryin March 2016. First oil from Ivar Aasen is planned for 4Q 2016.

The Ivar Aasen fi eld, formerly known as Draupne, is in water depth of 112 m (367 ft) west of the Johan Sverdrup fi eld on the Nor-wegian continental shelf. Det norske operates the project with 35% interest on behalf of partners Statoil (50%) and Bayerngas (15%).The fi eld has estimated reserves of 150 MMboe.

SMOE has contracted Wood Group Mustang to conduct topsides detailed engineering and design for the project.

HHI tapped for Aasta Hansteen topsides

Hyundai Heavy Industries won a $1.1 billion contract with Statoil to supply the topsides for the Aasta Hansteen spar platform.

Last year, HHI was also selected to build the hull for the facility, which will be the world’s largest spar to date and the fi rst to include storage for condensate. The 21,000-ton topsides will be designed to produce and process 23 MMcmoe/d of light oil and gas, and will be built with assistance from Houston-based CB&I. The 195-m (640-ft) hull, to be delivered under a cooperative agreement with Technip,will be equipped to store 160,000 bbl of condensate. �

Heerema Marine Contractors’ newbuild deepwater construction vessel

Aegir departed South Korea in January, 19 months after construction

began at the Daewoo Shipbuilding and Marine Engineering yard in

Okpo. After a stopover in China to load the first pipe reel, Aegir was

scheduled to sail to the Netherlands for installation of pipelay equip-

ment at the Huisman yard in Schiedam. The vessel is set to begin its

first project in the Gulf of Mexico in 4Q 2013. (Photo courtesy Heerema)

The Seven Viking ICE-C class inspection, repair and maintenance

vessel was unveiled and named at a Jan. 30 ceremony in Stavanger,

Norway. Co-owned by Subsea 7 and Eidesvik Offshore, the vessel en-

ters service in the North Sea under a five-year contract with Statoil. The

Seven Viking is based on Ulstein’s SX148 design, has a crew capacity

of 90 and can reach top speeds of 17 knots. (Photo courtesy Ulstein)

World Diamond, the first in a series of six PSV 3300 platform supply

vessels for Norway’s World Wide Supply, was launched at Damen Ship-

yards Group’s Galati, Romania, yard. The 80-m (262-ft) long vessel can

reach speeds up to 13.7 knots. (Photo courtesy Damen)

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








SEEKER™ S SeriesDirectional Drill Bits

An evolution in bit design and engineered

to maximize ROP in a variety of directional

applications while maintaining superior

directional control.

- ��

��

��

-� ��

��

��

-

For more information contact your local

sales representative or visit

www.nov.com/sks-series

Email: [email protected]© 2

012

Nat

iona

l Oilw

ell V

arco

All

Rig

hts

Res

erve

d.D

9210

0437

6-M

KT-

001

Rev

02

O n e C o m p a n y . . . U n l i m i t e d S o l u t i o n s

Proven PerformanceEagle Ford Shale, McMullen County, Texas

- 101% better ROP than average run

��

Seekingmore ROP?

Seek no more.

-� �� !��

��

-� "��

��

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.nov.com/sks-series

D R I L L I N G & P R O D U C T I O N Dick Ghiselin • Houston


The proliferation of unconventional plays has vaulted hydraulic fracturing into promi-nence as the ultimate way to establish com-munication between the wellbore and tight or unconventional reservoirs. Although the industry has been performing hydraulic fracture stimulation for half a century, the mainstream media acts like fracturing is something new.

For some time, industry experts have made it clear that hydraulic fracturing ap-pears to be the only viable way to turn un-conventional plays into economic successes. However, an innovative technique may have opened an alternative for certain specifi ccases. Given that it is not the fracturing it-self that is critical to success, but rather the resulting communication between the res-ervoir and the wellbore, the new technique may deliver suffi cient reservoir-to-well com-munication to eliminate fracture treatmentsand save considerable expense.

When fracturing was fi rst introduced to complete wells in unconventional plays such as shale gas or tight oil or gas reservoirs,the conventional wisdom was to produce a few, widely spaced fractures with very longhalf-lengths to deliver the commercial fl owrates necessary to ensure economic suc-cess. Subsequently, it was discovered that several closely spaced fractures of shortto moderate half-lengths produced more hydrocarbons because they signifi cantlyincreased recovery factors in the vicinity of the wellbore. Technology was quickly de-veloped to enable multi-stage fracturing to exploit this idea, and today’s development

plans include this feature.But hydraulic fracturing has always had

inherent risk. Because it is very diffi cult to control the propagation of a fracture withany degree of precision, it is hard to treatzones with nearby geohazards, such as aquifers. If the fracture intersects the geo-hazard, a good gas well may turn out to be a bad salt-water well. Typically, hydraulic fractures propagate as vertically oriented planes or fracture wings, whose height and half-length is a function of regional stresspatterns. Accordingly, it is common for frac-tures to propagate up or down to intersect nearby geohazards.

Nevertheless, hydraulic fracturing is the only practical way to access shale reservoirs.Permeability is so low that extensive reser-voir contact must be attained to providecommercial volumes of hydrocarbon. Butwith a moribund gas market, characterized by low demand and low commodity prices, many operators are only drilling shale gas wells when it is necessary to hold a lease. Many are switching their attention to the oil side, and for those folks there may be some good news.

Clipping the wings

By introducing a different way to com-municate with the reservoir, Radial Drilling Services Inc. has constructed more than 6,000 laterals in more than 1,000 wells using its patented lateral jetting system. Typically,four 100-m (328-ft) laterals can be jetted at any preselected horizon in a vertical or highly deviated wellbore without upward or

downward propagation, thus avoiding any nearby geohazards. Deployed on coiled tub-ing, the oriented jet heads pierce the rockto increase reservoir access by several or-ders of magnitude. Completed laterals can be used to enhance production by extending reservoir contact or to improve injection of water, steam, or CO2 for EOR projects. No conventional perforating or sliding sleeves are required. The number of levels to be treated on a single job is unlimited. In car-bonates, acid can be used as jetting fl uid to enhance penetration and generate worm-holes that increase reservoir contact. The technique has been implemented world-wide in both oil and gas/condensate wells. No proppant is deployed because the jetted hole resembles a perforation tunnel and is mechanically stable.

Jet heads incorporate erosional jets that actually cut the rock, and accelerating jets that push the head forward while circulat-ing cuttings back to the main wellbore. Inmany cases, the technology promises to en-able operators to construct communication paths between boreholes and the surround-ing reservoir without resorting to hydraulic fracturing.

A drilling shoe containing a J-slot is run to depth on tubing. Depth control can be as-sured by initially running a correlation log with a casing collar locator. Additionally, a cement bond log is recommended to ensure there is cement coverage at the spot to be treated. Presently, the minimum casing size is 4½-in. A work string of ½-in. to 5⁄8-in. stain-less tubing is run into the tubing. At the end of the work string is a small mud motor that drives a fl exible shaft consisting of several universal joints with a metal bit at the bot-tom end. The motor is actuated by pumping from the surface, and the bit drills a clean hole in the casing and cement sheath about 12 in. (30 cm) long.

The drilling assembly is then pulled out of the hole and replaced by a 330-ft (100-m) Kevlar-reinforced hose with a jet tip at the bottom end. The jetting assembly is cycled into the well to the drilled hole in the cas-ing/cement. Very high-pressure jetting is initiated to cut a hole in the formation. Cut-tings are allowed to fall into the rat hole. The drilling shoe is then rotated 90° and the pro-cedure repeated until four orthogonal holes have been constructed.

If desired, the drilling shoe can then be moved up to another level and another set of drain holes can be jetted. There is no limit to the number of stages that can be treated, but stainless tubing reels are presently limited to 12,000 ft (3,660 m) of tubing. Higher-capacity reels can be constructed if necessary. A com-plete animation of the entire procedure can be viewed at www.radialdrilling.com. �

The split drilling shoe uses a J-slot to guide the flexible drill string out at right angles to the casing

axis. When the jet is introduced, the J-slot guides it into the hole drilled in the casing and cement

sheath.

Technical innovation may stem frac attack

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








http://www.radialdrilling.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________





http://www.oceanicmc.com

G E O S C I E N C E S Gene Kliewer • Houston


Geosciences business

CGG closes Fugro Geoscience acquisi-

tion. CGG has closed its acquisition of Fu-gro’s Geoscience Division, with the excep-tion of the airborne activity and minor assets, which will be contributed when all operating licenses and administrative authorizations have been received.

The company also has simplifi ed its brand name from CGGVeritas to CGG, and has or-ganized around three divisions: Equipment, Acquisition and Geology, and Geophysics & Reservoirs.

The Equipment division includes Sercel business entities as well as Optoplan, Metro-log, GRC, and De Regt. The Acquisition divi-sion is made up of Marine Acquisition, Land Acquisition and Airborne Acquisition (once contributed), and includes General Geophys-ics, Electromagnetic and Gravity & Magnetic services. The GGR division includes: Multi-Client and New Ventures, Processing & Imag-ing, Jason and Hampson-Russell (Reservoir Characterization), Robertson (Exploration & Geology), and Data Management Services.

The agreement also includes the follow-ing partnerships:

• The creation of a Fugro (60%) and CGG (40%) joint venture, Seabed Geosolutions, focused on seabed acquisition

• A marketing and selling multi-client agree-ment for CGG to sell Fugro’s existing 3D data, which remains owned by Fugro

• A global technical and commercial mu-tual preferred supplier agreement.

Management completes Interica buy-out.

A management buy-out of the data manage-ment and software business from the Reser-voir Group has become effective. The Reser-voir Group decided that bespoke software and digital data management did not align with its strategy to specialize in downhole tools and as-sociated subsurface services

Simon Kendall, CEO of Interica said, “With the support of the vendors, we have executed this buy-out to deliver on our growth plans in ex-panding the scope and reach of the business for the benefi t of our extensive client base.”

Pascal Bartette, CEO of Reservoir Group, said “We are delighted that Interica is to emerge as a strong independent player able to offer new opportunities to existing staffand management. Reservoir is committed to remain supportive and looks forward to its continuing relationship with Simon Kendall and the able team he is leading.”

Survey status reports

TGS Nopec Geophysical has provided an update on some of its recent offshore seismic surveys. The company has fi nished the fi rst phase of a multi-year 2D seismic program in the Flemish Pass-Orphan basin area off-shore Newfoundland under a joint venture

with PGS. The remainder of the anticipated 20,000-km (12,427-mi) survey is expected to be completed this summer.

Offshore Colombia, the company has start-ed a 10,000-km (6,214-mi) 2D proprietaryprogram for the Agencia de Hidrocarburos.

TGS completed a 3,446-km (2,141-mi) 2D program in partnership with Fugro off north-east Greenland. The company aims to offer more than 7,500 km (4,660 mi) of new 2D data for this basin, which is to be the focus of a new license round in 2013.

In the Russian Arctic, TGS completed a 7,294-km (4,532-mi) 2D seismic survey in the Laptev and East Siberian seas.

During 4Q 2012, TGS and partner Dolphin Geophysical fi nished acquiring an 11,042-km (6,861-mi) 2D survey offshore Mauri-tania, representing the second phase of the NWAAM 2D multi-client program.

Offshore Angola, the company completed acquisition of a 12,500-sq km (4,826-sq mi) 3D survey covering deepwater blocks 35, 36, and 37. The aim is to image prospectivedeepwater presalt blocks thought to be anal-ogous to basins offshore Brazil. TGS also started work on a survey over the easternportions of blocks 36 and 37.

Off northwest Australia, TGS completed the Honeycombs 2,536-sq km (979-sq mi) 3D survey and the Three Bears 460-sq km (177-sq mi) 3D survey in the Carnarvon basin.

State Sevmorgeo Co. (SMG) has contract-ed WGP to conduct seismic survey operations in Ecuador. This activity will comprise the acquisition of 2D and 3D surveys in transi-tion zone and shallow waters. SMG will use Fairfi eld Z-700 Ocean Bottom Nodes in com-bination with portable sources provided and operated by WGP and installed on vessels of opportunity.

Afren has started the fi rst 3D seismic survey offshore the Seychelles in the Indian Ocean. The program comprises two surveys in the company’s license areas A and B, which extend over 14,319 sq km (5,528 sq mi). The fi rst program, covering 600 sq km

(231 sq mi), is on the southern portion of the licenses over the Bonit prospect. It will be fol-lowed by a survey on the northern section of the license area, covering 2,750 sq km (1,062 sq mi). Here there appears to be prospectiv-ity in both Cretaceous and Jurassic intervals.

Electromagnetic Geoservices ASA has re-ceived a letter of intent for six months of work offshore Asia. Upon the customer’s boardapproval, the 3D EM survey will begin this quarter using the BOA Thalassa. “We expect to deploy both the EM Leader and BOA Thalassa

in Asia for most of 2013 based on our substan-tially improved backlog as well as additional demand from both new and existing custom-ers,” said Roar Bekker, CEO of EMGS.

Chariot Oil & Gas Ltd. has completed a 3,500-sq km (1,351-sq mi) 3D seismic acqui-sition program offshore Mauritania in water depths ranging from 30 m (98 ft) up to 2,000 m (6,560 ft). The survey is expected to take 90 days to complete. The survey, in block C19, done by Fugro-Geoteam, targeted the south-west section of the block. “This 3D seismic survey fulfi lls Chariot’s initial three year work commitment within block C19 and is intended to identify structural and stratigraphic traps, with the latter in particular offering potential for large trap sizes,” Chariot said.

Seismic data forms the core of San Leon

Energy’s efforts to fi nd partners to explore the Durresi block offshore Albania. San Leon has hosted a data room for interested parties, and is keeping it open longer than scheduled to allow further time for more detailed technical evalu-ation and to accommodate new entrants. Last year, the company completed pre-stack depth migration of 840 sq km (324 sq mi) of 3D data over the block. Strong amplitude anomalies show at least three sand sections with 110-155 m (361-508 ft) of thickness separated by thick shale zones. Strong mud gas shows appeared in nearby similar sections during drilling of the well. The seismic responses are all constrained by faults. San Leon is performing further rein-terpretation and amplitude versus offset analy-sis of the data on Alban and other prospects. �

Seismic surveys on Atlantic OCS meet opposition in Senate

A plan to conduct some preliminary seismic surveys off the US East Coast has met opposition. The part of the US Five Year Outer Continental Shelf Oil and Gas Leasing Program for 2012-2017 that proposes seismic airgun surveys is under pro-test by a number of senators.

The plans would have testing done offshore from Delaware south to mid-Florida.The letter is from senators Lautenberg, Whitehouse, Leahy, Menendez, Cardin,

Mikulski, Boxer, and Cantwell. All are Democrats and represent, among them, New Jersey, Rhode Island, Vermont, Maryland, California, and Washington.

Meanwhile, three East Coast governors wrote Sally Jewell, new nominee as Secre-tary of the Interior, making clear that they want to hear the nominee express her sup-port for oil and gas development in Atlantic waters during her confirmation hearing.

“Energy production from the Atlantic outer continental shelf could create morethan 140,000 new jobs within the next 20 years, and we hope you will ensure that the administration is a partner with the states on this issue,” said North Carolina Gov. PatMcCrory, South Carolina Gov. Nikki Haley, and Virginia Gov. Robert McDonnell.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








cgg.com

Today the industry has a new Geoscience leader.

Our global community of talented geoscientists work

closely with our clients to deliver innovative solutions for

the exploration and sustainable development of the Earth’s

natural resources.

With a proven track record and a proud heritage of more

than 80 years, we are your geoscience partner of choice.

We are CGG.

PASSION FOR

GEOSCIENCE

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.cgg.com

More than just a little rust, corrosion has

a big impact on reliable equipment operations,

especially in the harsh offshore environment.

O F F S H O R E A U T O M AT I O N S O L U T I O N S


Ian Verhappen

Industrial Automation Networks Inc.

Estimates from a variety of sources put the cost of corrosion at 3 to 5% of GDP, ormore than $2 trillion per year. The econom-ic impact of corrosion is more than “lost metal”: it also includes lost production fromunscheduled outages and potential risks to health, safety and the environment. And, as several pipeline companies have learned in the past few years, there is also the impact on one’s social license to operate, which is then refl ected in company share price. The offshore environment is more at risk to cor-rosion that land-based equipment due to salt water and the repetitive stress caused by wave motion.

Metallurgists are always striving to re-duce this impact. However, it is often dif-fi cult to gather data to make informeddecisions. Fortunately, new tools and tech-nologies are becoming available to allow both real-time corrosion rate informationas well as reconciliation of a range of data sources to provide useful information on the status of equipment at greater speeds than in the past.

A number of manufacturers have devel-oped products to measure corrosion rates in real time, and in doing so are making the labor-intensive corrosion coupons that have been the backbone of industrial corrosionmonitoring for more than 50 years obsolete. Corrosion coupons are simple to use and areusually accurate, but they are completelymanual: the measurements must be made offl ine, and are labor intensive. Coupons must be pre-weighed, distributed to remotelocations, installed, retrieved, examined, cleaned, and re-weighed before data is pro-cessed.

The new products take advantage of to-day’s micro-processing power to use the in-formation from single transmitters making multiple parallel measurements to a single output correlated to the corrosion rate in the vessel, pipe, or ducting as appropriate. The data is transmitted to a central computer, where it is integrated with other software tomeasure and monitor the corrosion rate and the effectiveness of countermeasures taken

to minimize it. There are two forms of mea-surements:

• Electrical Resistance (ER) probes pro-vide on-line data about corrosion rates to check the effi cacy of corrosion inhi-bition or detect changes in underlying process corrosivity.

• Linear Polarization Resistance (LPR) is a fast-responding intrusive method for measuring changes in the corrosivity of aqueous solutions, though the presenceof oil in the process stream may affectthis form of measurement.

The measurements themselves quantify changes in current density due to material loss. Much like a pH meter, or Wheatstone bridge, a comparison is made between a sample and reference measurement to pro-vide a signal-conditioned, calibrated output.

With real-time data available, it is possible correlate a spike in corrosion rate with a fa-cility operating condition, ambient environ-ment situation (rain, high wind, freezing, or high temperature) or time of day (sunrise, sunset, shift change, etc.). Appropriate ac-tions can then be taken to reduce the sourceof the increased corrosion rate, prevent its recurrence, and thus reduce the overall an-nual or compound corrosion rate and extend the life of that component.

Because these sensors tend to be dis-tributed in a wide range of locations, and in many cases where a signal cable may not be available, many of these monitoring systems rely on wireless technology to transmit the process reading. These wireless networks typically require installation of a backhaul of backbone to bring data from all the devices back to a central monitoring station, which in some cases is a distributed control sys-tem, or DCS. This same wireless networkinfrastructure, which is often based on IEEE 802.11 protocols (WiFi), can also be used to collect data from inspectors as they are doing their manual readings, such as ultra-sonic testing at critical points for localized pitting, or cracking corrosion directly fromtheir measurement tools to the corrosionmonitoring system. Such measures helpprevent transcription errors and reduce the time associated with manual data entry, so that inspectors may spend their time analyz-ing the data and planning corrective actions.

Online corrosion tools, by their nature, present an average corrosion rate, where av-erage applies to the surface area of the “cor-rosion coupon” from which the measure-ments are made. As a result, other offl inetools such as “smart pigs” and the above-mentioned ultrasonic measurement tools are required to complement the measure-ments. Both of these techniques require ahigh degree of manual intervention eitherto launch and receive the pigs, or to place the ultrasonic test tool at the right locations on the pipe or vessel. Fortunately, both tech-niques are able to detect concentrated or localized corrosion rates that result in pin-holes and associated leak sources.

The above tools are predominantly used to monitor for internal corrosion; unfortu-nately, the majority of metal in the oil and

gas environment is either covered with insu-lation or submerged, so external corrosioncannot be observed simply by walking past and looking for rust spots. One way to es-timate the corrosion rate under coatings is to correlate cathodic protection current with rate as an indicator of how much metal is be-ing sacrifi ced to prevent potential corrosion.Once again, wireless technologies are oftenused to gather this information and send it back to a central repository for analysis.

More than just a little rust, corrosion has a big impact on reliable equipment opera-tions, especially in the harsh offshore envi-ronment. We are fortunate that a number of related technologies are evolving to allow us to better track the impact of corrosion in real time, combined with better analytical and diagnostic off-line tools to reverse the corrosion trend, especially as some of our aging infrastructure is approaching its end of design life corrosion margins. �

AuthorIan Verhappen, P.Eng. is an ISA Fellow, ISA Certifi ed

Automation Professional (CAP), and a recognized au-

thority on process analyzer sample systems, Foundation

Fieldbus and industrial communications technologies.

Verhappen operates a global consultancy, Industrial

Automation Networks Inc., specializing in fi eld level

industrial communications, process analytics and

hydrocarbon facility automation. Feedback is always

welcome via e-mail at [email protected].

High-tech tools help cut the costs of corrosion

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








N o l i m i t s

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________________________





http://www.bluebeam.com/assessrisk


G E O L O G Y & G E O P H Y S I C S

Seismic survey vessel capabilities

go up while count goes down

The 2013 tally of seismic vessels world-wide is 142, down eight from 2012. This decrease in number is offset par-tially by the addition of new, high-ca-pacity vessels capable of conducting a

variety of surveys from 2D through 4D.Among the new vessels are the following:• HYSY 708 – China Oilfi eld Services Ltd.• HYSY 720 – China Oilfi eld Services Ltd.• European Supporter – Fairfi eldNodal• Damon Chouest – Fairfi eldNodal• Fugro Brasilius – Fugro Brasil• Fugro Equinox – Fugro Survey Pty. Ltd.• Fugro Supporter – Fugro Survey Pty. Ltd.• Ramform Titan – PGS• Ramform Atlas – PGS.In the category of geosciences business,

CGG has made its voice heard in the past year. First, CGGVeritas agreed to acquire Fugro’s Geoscience Division, with the ex-ceptions of existing multi-client library andnodes, for €1.2 billion ($1.55 billion). The agreement includes:

• Creation of a seabed joint venture fo-cused on the seabed acquisition mar-ket, which will be 60%-owned by Fugroafter payment of €225 million ($291.6 million) to CGGVeritas

• A commercial agreement for CGGVeri-

tas to sell Fugro’s existing multi-client data, which remains owned by Fugro

• A global strategic technical and com-mercial mutual preferred supplier agree-ment.

In conjunction with announcing the sign-ing of the main agreements needed to com-plete the acquisition of Fugro’s GeoscienceDivision, CGGVeritas also established a new identity. The name has been shortened to CGG and now is organized into divisions for Equipment, Acquisition and Geology, andGeophysics and Reservoirs.

BP is building in Houston what it says will be the largest commercial supercomputing complex in the world. The High-Performance Computing center is scheduled to open in mid-2013 and will be the worldwide hub for processing and managing geologic and seis-mic data across all of BP’s assets. The HPC will have 67,000 CPUs and is expected to pro-cess data at a rate of as much as two petafl ops.

The total memory will be 536 terabytes and the disk space will total 23.5 petabytes.

One interesting new project is the collabo-ration between CGG and Saudi Aramco to de-velop an AUV technique for seabed seismic acquisition. The SpiceRack project intends to develop, manufacture, and commercial-ize a system for automated deployment and retrieval of self-propelled recording nodes. The invention will be programmed to reacha specifi c subsea location and will launch itself, record data while resting on the sea-bed, and return to the recapture vessel for automated retrieval and data download.

Sercel launched a new marine surveydesign software module for its SeaPro Nav Suite. Sercel said SeaPro Design can gener-ate surveys from simple to complex designs in 2D, 3D, or multi-vessel formats.

Sercel also released its latest generation Sentinel solid streamer, the RD. It has a smaller diameter and weighs 15% less, said Sercel, to reduce cable drag and increasestorage capacity onboard seismic vessels.

Halliburton’s Landmark Software and Ser-vices has bought Petris Technology Inc. Pe-trisWINDS products will become available as part of Landmark’s DecisionSpace portfolio. This includes Recall, DataVera, DrillNET, and

Gene Kliewer

Technology Editor, Subsea & Seismic

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








www.offshore-mag.com • March 2013 Offshore 33


the Operations Management Suite.Halliburton said it now can deliver easy

access to its reservoir and well technical data to improve decision-making by provid-ing mission-critical data in a timely manner.

Octio and Siemens have partnered in per-manent reservoir monitoring. Siemens will contribute project management and execu-tion, subsea system design, power and com-munication, as well as subsea system manu-facturing. Octio contributes its Permanent Oilfi eld Monitoring technology based on a digital network including high vector fi del-ity seismic MEMS sensors with interface to EM, chemical, biological, and oceano-graphic sensors. The system is built for per-manent deployment on the seafl oor with a 25-year lifetime. Once installed, the system can perform passive monitoring as well as repeated seismic surveys of the reservoir.

ION Geophysical Corp. has released its next generation redeployable seabed seis-mic acquisition system. The Calypso system uses ION’s VectorSeis digital sensors and is designed to operate twice as deep and twice as effi ciently as the prior generation system.

ION says its new Calypso system has the potential to mitigate barriers to wider adop-tion by doubling cable lengths and produc-

tivity while increasing the operating depths.Calypso offers the following improvements:• Tilt-insensitive multi-component (4C)

VectorSeis sensors• Buoy-based recording• Unlimited number of cables with twice

the length (12-14 km, or 7.5-15 mi)• Water depths to 2,000 m (6,562 ft).

New vessels on the horizon

Petroleum Geo-Services (PGS) has signed charter agreements with PF THOR for four new seismic support vessels. They will be built in Besiktas, Turkey, owned and oper-ated by PF THOR, and taken by PGS on 10-year time charter contracts, with options for extension. Delivery is scheduled for 3Q 2014 onward. The vessels will support PGS’s seis-mic fl eet by providing offshore bunkering, crew change assistance, supply of provision and spare parts, and support during in-sea maintenance of seismic equipment.

The propulsion systems, PGS adds, allow the vessels to operate with minimal fuel con-sumption, enabling fuel cost savings of up to 60% compared with the company’s current vessels.

Beyond that, PGS has ordered two more Ramform Titan-class seismic vessels from

Mitsubishi Heavy Industries Ltd. and ex-ercised an option for two more. Two of the four vessels are planned for delivery in 2013 with the remaining two scheduled to be completed in 2015.

The Titan-class vessels are 104.2 m (342 ft) long, 70 m (230 ft) wide, and have a 6.4 m (21 ft) draft. Transit speed is 16 knots with diesel electric power totaling 18 MW. Each holds two 30-ft workboats and 24 x 12,000 m (39,360 ft) capacity streamer winches.

Dolphin Geophysical AS has christened the M/V Polar Duchess. The vessel is under contract to TGS and will start soon in a sur-vey in the Barents Sea. The vessel is a pur-pose built 3D seismic vessel, capable of tow-ing 14 streamers at 100 m (328 ft) separation rigged with Sercel SSAS Sentinel streamers.

Sanco Shipping AS has exercised an op-tion for a second seismic vessel to be built by Kleven Maritime at the Myklebust Verft yard in Norway.

The Sanco Sword, scheduled for delivery in 1Q 2014, is an STY 324 CD design from Skip-steknisk AS and sister vessel to the Sanco

Swift which is scheduled for delivery in July 2013. Dolphin has signed a fi ve-year charter for the Sword with three options to extend the charter for two years per option. �

OBC graphic courtesy RXT.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Worldwide Seismic Vessel Survey

Vessel

name

Year

rigged o

r co

nve

rted

Tota

l le

ngth

(m

)

Tota

l beam

(m

)

Str

eam

er

confi

gura

tion

(# s

tream

ers

x

# c

hannels

)

Vess

el

ava

ilabil

ity

(Yes,

No,

or

Exc

lusi

ve c

ontr

act

)

Pri

mary

regio

n

Sourc

e a

rray

confi

gura

tion a

s ri

gged (

# a

rrays

x

capaci

ty i

n c

u i

n.)

Maxi

mum

tow

able

fo

otp

rint (#

cable

s x

length

(m

) x

wid

th (

m))



BGP, 5th Floor, Building E5C West, 3rd Street; TEDA, Tainjin 300457, P.R.China

BGP Challenger 2009 55 13.8 1 x 1,200 Yes AF, MID E, FAR E 1 x 9,000

BGP Explorer 2010 64 16 1 x 5,200 2 x 3,480

BGP Pioneer 2006 83.7 19.5 6 x 640 Yes AF, MID E, FAR E 2 x 3,400 6 x 8,000

BGP Prospector 2011 100 24 2 x 960 2 x 5,620

Dong Fang Kan Tan 2007 65.8 13.8 1 x 1,200 Yes AF, MID E, FAR E 1 x 3,000 No. 2 (BGP Researcher)

Caspian Services Group Limited, Office Building B, 7th Acreage, The Esplanade, Microdistrict 15, Aktau 13000, Kazakhstan

Caspian Galiya 2007 12.5 4.5 Yes Caspian OBC Cable

Coastal Bigfoot 2007 12.5 4.5 Yes Caspian OBC Cable

CGG, 27 avenue Carnot, 91341 Massy Cedex, France

Oceanic Vega 2010 106 28 20 x 640 Yes Worldwide 2 x 5000 20 x 8000 x 100

Oceanic Sirius 2011 106 28 20 x 640 Yes Worldwide 2 x 5000 20 x 8000 x 100

Alize 1999 101 29 16 x 640 Yes Worldwide 2 x 5000 16 x 8000

Amadeus 1999 84 19 8 x 640 Yes Worldwide 2 x 5000 8 x 8000 x 100

Princess 2001 76 14 3 x 560 Yes Worldwide 2 x 5000 3 x 6000 x 100

Symphony 2000 121 23 12 x 640 Yes Worldwide 2 x 5000 12 x 8000 x 100

Venturer 2007 90 15 4 x 640 Yes Worldwide 2 x 5000 4 x 8000 x 100

Viking 1998 93 22 10 x 640 Yes Worldwide 2 x 5000 14 x 8000 x 100

Viking II 1999 93 22 8 x 640 Yes Worldwide 2 x 5000 8 x 8000 x 100

Viking Vanquish 2007 93 22 12 x 640 Yes Worldwide 2 x 5000 12 x 8000 x 100

Veritas Vantage 2002 93 22 10 x 640 Yes Worldwide 2 x 5000 10 x 8000 x 100

Viking Vision 2007 105 26 14 x 640 Yes Worldwide 2 x 5000 14 x 8000 x 100

Bergen Surveyor 1997/ 2006 67 15 2 x 560 Yes Worldwide 2 x 5000 2 x 6000 x 100

Geowave Champion 2007 106 22 14 x 640 Yes Worldwide 2 x 5000 14 x 8000 x 100

Geowave Voyager 2008 93 22 10 x 640 Yes Worldwide 2 x 5000 10 x 8000 x 100

Oceanic Endeavour 2008 107 27 16 x 640 Yes Worldwide 2 x 5000 16 x 8000 x 100

Challenger 2006 90 19 12 x 640 Yes Worldwide 2 x 5000 12 x 8000 x 100

Oceanic Phoenix 2011 114 25 14 x 640 Yes Worldwide 2 x 5000 14 x 8000 x 100

Pacific Finder 2011 68 17 4 x 640 Yes Worldwide 2 x 5000 4 x 8000 x 100

Geo Coral 2010 108 28 16 x 640 Yes Worldwide 2 x 5000 16 x 8000 x 100

Geo Caspian 2010 108 28 16 x 640 Yes Worldwide 2 x 5000 16 x 8000 x 100

Geo Caribbean 2008 101 28 14 x 640 Yes Worldwide 2 x 5000 14 x 8000 x 100

Geo Celtic 2006 101 28 12 x 640 Yes Worldwide 2 x 5000 12 x 8000 x 100

Geo Atlantic 2006 121 22 10 x 640 Yes Worldwide 2 x 5000 10 x 8000 x 100

Geo Barents 2007 77 21 8 x 640 Yes Worldwide 2 x 5000 8 x 8000 x 100

China Oilfield Services, Ltd., No.6 Dongzhimenwai Xiaojie Beijing 100027 P.R.C

Bin Hai 511 1979 81 13.4 3 x 360 Yes China, Asia, CIS 2 x 2,490

Bin Hai 512 1979 79 13.4 4 x 360 Yes China, Asia, CIS 2 x 3,000

Bin Hai 517 1997 60 15 2 x 480 Yes China, Asia, CIS 4,075

HYSY 718 2005 78 18 6 x 480 Yes China, Asia, CIS 2 x 3100

HYSY 719 2008 80 18 8 x 480 2 x 4,110

Dong Fang Ming Zhu 1994 79 16.5 4 x 480 2 x 3,185

Nan Hai 502 1980 66 11 2 x 360 Yes China, Asia, CIS 3,660

HYSY 708 2013

HYSY 720 2013

Dalmorneftegeophysica (DMNG), 426, Mira Ave., Yuzhno-Sakhalinsk, 693004, Russia

Akademik Fersman 2007 81.5 14.8 SEAL 1 x 960 Contact SE Asia / Worldwide 4 x 5,000 1 x 1,100

Orient Explorer 2011 81.8 14.8 4 x 1,440 Contact SE Asia / Worldwide 6 x 2,920 4 x 6,000 x 150

Zephyr-I 2007 81.8 14.8 SEAL 1 x 960 Contact SE Asia / Worldwide 4 strings 2,940 higher on request 1 x 11,100

FairfieldNodal ,1111 Gillingham, Sugar Land, Texas 77478, USA

Fairfield New Venture 2004 76 18 Shooting Vessel Yes GoM 5,330 dual

Fairfield Challenger 2005 67 14 Shooting Vessel Yes GoM 5,330 dual

Fairfield Pursuit 2011 59 14 Shooting Vessel Yes GoM 5,330 dual

Carolyn Chouest 2010 73 16 Node Handling Vessel Yes GoM Node Vessel 1200 Nodes

C-Pacer 2011 80 18 Node Handling Vessel Yes GoM Node Vessel 2400 Nodes

European Supporter 2012 95 18 Node & Shooting vessel Yes GoM 5,330 dual 3000 Nodes

Damon Chouest 2012 73 18 Node & Shooting vessel Yes GoM 3000 Single 300 Nodes

Fugro Odyssey 2003 (rebuilt) 39.9 7.6 1x Sercel Sentinel up to 1,5Km (120 ch) Yes Brasil 4x40 cu inch sleeve gun cluster N/Aor single 210 cu inch GIGun

Fugro Brasilis 2012 65.65 14 1x Sercel Sentinel up to 1,5Km (120 ch) Jun-12 Brasil 4x40 cu inch sleeve gun cluster N/Aor single 210 cu inch GIGun

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Acq

uis

itio

n

capabil

ity

Acq

uis

itio

nca

pabil

ity

Technical capability Onboard processing

Seismic


2D

3D

4C

/4D

Shall

ow

transi

tion z

one

Deepw

ate

r

Hig

h d

ensi

ty

Oce

an b

ott

om

ca

ble

Vari

able

depth

Nav

data

QC

data

Full

data

Fin

al

pri

mary

reco

rdin

g m

edia

(typ

e o

r ca

rtri

dge #

)

Sate

llit

e t

ransm

issi

on

to s

hore

(co

mpany

use

d

and t

ransm

issi

on

speed (

baud )

)


x x x 3592 Inmarsat VSAT

x x x 3592 Inmarsat C

x x x 3592 VSAT

x x x 3592 Inmarsat C,F VSAT

x x 3592 VSAT

x x x x x x x x

x x x x x x x x

x x x x x x x x x 3592 VSAT ≥ 128k




x x x x x x x x x x 3592 VSAT ≥ 128k





















x x >10 m x x x x x 3590 Inmarsat

x x >10 m x x x x x 3590 KU

x x >8 m x x x x 3590

x x 3590 KU

3590

x x 3590 KU

x x >10 m x x x x x 3590

x x x x x x 3590 VSAT

x x x x x x x x 3590 VSAT

x x x x x x 3590 VSAT

x x x x x x x x 3590

x x x x x x x x x 3590

x x x x x x x x x 3590

x x x X x x x x x 3590

x x x x x x Hard Drive No

x x x x x x x Hard Drive Yes

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM










Vessel

name

Year

rigged o

r co

nve

rted

Tota

l le

ngth

(m

)

Tota

l beam

(m

)

Str

eam

er

confi

gura

tion

(# s

tream

ers

x

# c

hannels

)

Vess

el

ava

ilabil

ity

(Yes,

No,

or

Exc

lusi

ve c

ontr

act

)

Pri

mary

regio

n

Sourc

e a

rray

confi

gura

tion a

s ri

gged (

# a

rrays

x

capaci

ty i

n c

u i

n.)

Maxi

mum

tow

able

fo

otp

rint (#

cable

s x

length

(m

) x

wid

th (

m))


Fugro GeoServices, 200 Dulles Blvd., Lafayette, Louisiana USA

Fugro Enterprise 2007 52 12 1 x 48, 1 x 96 Yes GoM 90-300 GI Guns

Geodetic Surveyor 1985 37 9 1 x 48, 1 x 96 Yes GoM 90-300 GI Guns

Universal Surveyor 1980 37 9 1 x 48, 1 x 96 Yes GoM 90-300 GI Guns

Fugro OSAE GmbH, Fahrenheitstrasse 7, 28359 Bremen, Germany

Fugro Gauss 1980/2007 69 13 (Mobile) Yes Atlantic (Mobile) (Mobile)

Fugro Survey Ltd., Denmore Rd, Bridge of Don, Aberdeen AB23 8JW, UK

Fugro Galaxy 2011 65.2 14 1 x 144 Yes NWECS 140

Fugro Meridian 1982/1997 72.5 13.8 1 x 240 Yes NWECS 140/1,000

Geo Prospector 1970/1997 72.6 11.8 1 x 120 Yes EAME 140

Fugro Discovery 1997/2007 70 12.6 1 x 120 Yes NWECS 140

Fugro Searcher 2010 65.2 14 1 x 240 Yes NWECS 140/1,000

Fugro Survey Africa (Pty) Ltd, Unit 24 Woodbridge Business Park, 7441 Milnerton, Cape Town, South Africa

Geo Endeavour 1985/1998 45.7 10 1 x 48 Yes Subsaharan Africa 1 x 90, 1 x 150

Fugro SAE, 17 Port Said St., Maadi, Cairo, Egypt

Fugro Navigator 1988/2009 54 11 1 x 120 Mid-2013 Med 1 array, 140 cu in

Fugro Survey Pte Ltd, 35 Loyang Crescent, Singapore 509012

Fugro Equator 2012 65 14 1 x 240 41579 Far East Mini G 4 x 40 / 4 x 20

Fugro Equinox 2011 60 16 1 x 120 41365 Far East Sleeve 4 x 40 / 4 x 20

Amarco Tiger 1975 / 2008 53 11.5 1 x 120 Yes Far East Sleeve 4 x 40 / 4 x 20

Fugro Supporter 1994 / 2013 75.4 12.5 (Mobile) Yes Far East (Mobile) (Mobile)

Fugro Survey (India) Pvt. Ltd., Fugro House, D-222/30, T.T.C. Industrial Area, M.I.D.C.,Nerul,Navi Mumbai - 400 706. Maharashtra. INDIA Tel : +91 22 27629500 Fax : +91 22 2762 9140

Flamboyan 1983 / 2010 39 9.5 As required Yes India As required

Gardline, Endeavour House, Admiralty Rd., Great Yarmouth, Norfolk NR30 3NG UK

Sea Explorer 1993/1994/ 58.8 11 1 x 120 Yes Worldwide 2 x 160 2004

Ocean Endeavour 2004 64.4 11.4 1 x 120 Yes Worldwide

Sea Proflier 1992 65.7 11 1 x 120 Yes Worldwide 2 x 160

Sea Surveyor 1998/1999 64.4 11.4 1 x 480 Yes Worldwide 1 x 160 up to 1,950

Sea Trident 1984/1991/ 57.9 10.2 1 x 120 Yes Worldwide 2 x 160 2006

Ocean Seeker 1970/2000 80.7 13 1 x 120 Yes Worldwide 1 x 160

L’Espoir 1971/1996 67.5 10.6 1 x 120 Yes Worldwide 1 x 160

Tridens 1 1984/1991 57.9 10.2 1 x 120 Yes Worldwide 1 x 160

Global Geophysical Services, 13927 S. Gessner Rd., Missouri City, TX 77489 USA

James H. Scott 2005 70 ft 22 ft Yes GOM, International 4 x 750 cu in. Source

Global Longhorn 2007 93.9 ft 26 ft Yes GOM, International Accommodation

Global Mirage 2008 65 ft 21 ft Yes India, International 2 x 750 cu in Source

Global Vision 2007 65 ft 21 ft Yes India, International OBC Cable

Global Quest 2007 65 ft 18 ft Yes India, International OBC Cable

Lori B 2007 48 ft 20 ft Yes GOM OBC Cable

Tiny Tune 2005 38 ft 12 ft Yes USA Source

Kiwi I 2007 54 ft 16 ft Yes GOM OBC Cable

Kiwi II 2007 49 ft 13.8 ft Yes GOM OBC Cable

Kiwi III 2008 47 ft 16.4 ft Yes GOM OBC Cable

Cobourg 2008 52.5 ft 17.4 ft Yes India, International OBC Cable

Marine Arctic Geological Expedition (MAGE)

Geolog Dmitriy Nalivkin 1985 71.7 12.8 1 x 648 Contract Arctic, Northern seas 1 x 3,410 1 x 8,100

Professor Kurentsov 1976 68.9 12.4 1 x 648 Contract Arctic, Northern seas 1 x 8,100

NAUTIC Offshore AS, Dronningen 1, 0211 Oslo, Norway

Neptune NAIAD 2008 66.3 14.2 4 x 2,560 Yes Worldwide 2x 4,000 4 x 6,000 x 100

Offshore Seismic Surveys, OSS, 13430 NW Freeway, Suite 800, Houston TX 77040

OSS Gulf Supplier 56.4 11.6 3 x 240 Yes South America 2 x 1,500 3 x 3,000 x 200

OGS Italy, Borgo Grotta Gigante 42c, P.O. Box 2011, 34016 Trieste, Italy

OGS Explora 8 71.9 12.8 1 x 96 Worldwide inc. 2 x 355 Antarctic

Orogenic GeoExpro, Loyang Crescent, Loyang Offshore Supply Base, Block 217, SOPS Avenue, Box No. 5043, Singapore 508988

Genesis 1995/2006 52 11 1 x 120 Channel TBA Asia Pacific Single GI Gun 90/150/210 cu.inch N/A

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Acq

uis

itio

nca

pabil

ity

Acq

uis

itio

nca

pabil

ity


Seismic

2D

3D

4C

/4D

Shall

ow

transi

tion z

one

Deepw

ate

r

Hig

h d

ensi

ty

Oce

an b

ott

om

ca

ble

Vari

able

depth

Nav

data

QC

data

Full

data

Fin

al

pri

mary

reco

rdin

g m

edia

(typ

e o

r ca

rtri

dge #

)

Sate

llit

e t

ransm

issi

on

to s

hore

(co

mpany

use

d

and t

ransm

issi

on

speed (

baud )

)


x x x x x x Hard Drive V-Sat



x x x x x x (Mobile) TBA

x x x x x x LT04 Marlink





x x x x x

x x x x x x x Hard Disk

X X X X X X X 3490E VSAT 256 Kbit

X X X X X X X 3490E VSAT 128 Kbit

X X X X X X X 3490E TBA

X X X X X X X (Mobile) VSAT 256 Kbit

x x x x DLT FB

x x >10m x x x x x 3490E VSAT (256)

x x

x >10m x x x x x 3490E VSAT (256)

x x >10m x x x x x 3490E VSAT (256)

x >10m x x x x x 3490E VSAT (128)

x >10m x x x x x 3490E VSAT (256)

x >10m x x x x x 3490E VSAT (128)

x >10m x x x x x 3490E Gardline 64k

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x x x

x x x x x x 3590, 3592 Iridium Open port Skansat CT TT-3020C

x x x x x x 3590, 3592 Inmarsat-C Skanti “Scansat CT”Inmarsat Mini-M SP 2000M Inmarsat

Fleet-77 “Thrane and Thrane AS”

x x x x x x x x 3590, EHD, USB VSAT

x x x x 3590 V-SAT

x x x x x x 3490E 64k

x x x x 3590 VSAT

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM










Vessel

name

Year

rigged o

r co

nve

rted

Tota

l le

ngth

(m

)

Tota

l beam

(m

)

Str

eam

er

confi

gura

tion

(# s

tream

ers

x

# c

hannels

)

Vess

el

ava

ilabil

ity

(Yes,

No,

or

Exc

lusi

ve c

ontr

act

)

Pri

mary

regio

n

Sourc

e a

rray

confi

gura

tion a

s ri

gged (

# a

rrays

x

capaci

ty i

n c

u i

n.)

Maxi

mum

tow

able

fo

otp

rint (#

cable

s x

length

(m

) x

wid

th (

m))


PGS Strandveien 4, 1326 Lysaker Norway

Atlantic Explorer 1994 91.5 18 6 x 480 Yes Worldwide 2 x 4,130 3.6 sq km

Nordic Explorer 1993 81.1 16.5 1 x 804 Yes Worldwide 2 x 4,130

Pacific Explorer 1994 91.4 22 6 x 564 Yes Worldwide 2 x 4,130 3.5 sq km

Ramform Challenger 1996 86.2 39.6 14 x 564 Yes Worldwide 2 x 4,135 6.35 sq km

Ramform Explorer 1995 83 39.6 10 x 564 Yes Worldwide 2 x 4,130 6.35 sq km

Ramform Valiant 1998 86.2 39.6 16 x 648 Yes Worldwide 2 x 4,130 8.9 sq km

Ramform Vanguard 1999 86.2 39.6 16 x 648 Yes Worldwide 2 x 4,130 8.9 sq km

Ramform Viking 1998 86.2 39.6 16 x 648 Yes Worldwide 2 x 4,130 8.9 sq km

Ramform Sovereign 2008 102.2 40 18 x 648 Yes Worldwide 2 x 4,130 10.9 sq km

Ramform Sterling 2009 102.2 40 18 x 648 Yes Worldwide 2 x 4,130 10.9 sq km

PGS Apollo 2010 106.8 19.2 10 x 648 Yes Worldwide 2 x 4,135 8.1 sq km

Sanco Spirit 2011 86 16 1 x 804 Yes Worldwide 2 x 4135

Ramform Titan 2013 104.2 70 20 x 648 Q2 Worldwide 2 x 4135 12.2 sq km

Ramform Atlas 2013 104.2 70 20 x 648 Q4 Worldwide 2 x 4135 12.2 sq km

Polarcus, Almas Tower, Level 32, Jumeirah Lakes Towers. P.O. Box 283373, Dubai, U.A.E.

Polarcus Nadia 2009 89 19 10 x 648 Yes Worldwide 2 x 4240 10 x 8100 x 100

Polarcus Naila 2010 89 19 10 x 648 Yes Worldwide 2 x 4240 10 x 8100 x 100

Polarcus Asima 2010 92 21 12 x 648 Yes Worldwide 2 x 4240 12 x 8100 x 100

Polarcus Alima 2011 92 21 12 x 648 Yes Worldwide 2 x 4240 12 x 8100 x 100

Polarcus Amani 2012 92 21 14 x 648 Yes Worldwide 2 x 4240 14 x 8100 x 100

Polarcus Adira 2012 92 21 14 x 648 Yes Worldwide 2 x 4240 14 x 8100 x 100

REFLECT Geophysical Pte. Ltd., 8 Temasek Boulevard #04-02, Suntec Tower Three, Singapore 038988

Geowave Commander 1998/2006 93.5m 16.5m 4 x 640 Yes Worldwide 2x 3,450 6 x 8,000 x 100

Refect Scorpio 1982/2007 64.4 18.5 4 x 480 Yes Worldwide 2x 3,500 4 x 6,000 x 100

RXT Reservoir Exploration Technologies Lysaker Torg 5 A, PO Box 104, 1325 Lysaker, Norway

Ark Phil 2007 70 16.8 cable vessel

Beulah Chouest 1982/1996 60 14 980 channels Yes Worldwide 3 x 1,340 6 x 6,000

Bourbon 2004 64 17 cable vessel Yes Worldwide 6 x 6,000

Ocean Pearl 2001 108.6 18 Yes Worldwide 2 x 3,990 12 x 6,000

Sanco Star 2008 (combined source/cable vessel) Yes Worldwide

Ramco Express 2003 58 12.5 2 x 6,000

Sara Maatje IX 1994 Yes Worldwide 8 6-km VSO cables

Sea Bird Exploration Nedre Vollgate 3, P.O. Box 1302, Vika 0112 Oslo, Norway

Aquila Explorer 2007 71 17.5 1 x 960 PGS Worldwide 2 x 5,000

Harrier Explorer 2007 81 18.3 Source PGS Worldwide

Hawk Explorer 2006 66 14.5 1 x 960 Fugro Geoteam Worldwide 1 x 4400

Munen Explorer 2007 60 14 1 x 960 Yes Worldwide 2 x 5,000

Northern Explorer 1987/1998/ 76 14 1 x 960 Yes Worldwide X 5,000 Bolt 2004

Osprey Explorer 2006 81 16 Source Yes Worldwide 2 X 5000 (client selectable)

Voyager Explorer 68 16 2

Geo Pacific 2003 82 20 8 x 480 6 x 8,999

Sevmorneftegeofizika (SMNG), 17, Karl Marx St., 183025 Murmansk, Russia

Akademik Lazarev 1987/96 81.8 14.8 1 x 960 Yes Worldwide 4 x 4,200 1 x 12,000

Akademik Nemchinov 1988/97 84 14.8 4 x 480 Yes Worldwide 6 x 7,874 4 x 6,000 x 100

Akademik Shatskiy 1986/91 83.5 14.8 1 x 960 Yes Worldwide 6 x 6,444 2 x 6,000 x 100

Geo Arctic 1988/97 84 14.8 1 x 960 Yes Worldwide 4 x 4,820 1 x 12,000

Iskatel - 5 1989/97 49.2 18.2 1 x 480 Yes Worldwide 4 x 3,000 1 x 6,000

Professor Rjabinkin 1989/1995/ 49.9 10.5 2 x 800 Yes Worldwide 2 x 2,280 1 x 6,000 2007

Vyacheslav Tikhonov 2011 84.2 17 8 x 480 Yes Worldwide 6 x 4,240 6 x 8,100 x 150

Shanghai Offshore Petroleum Bureau SINOPEC, 1225 Shangcheng Road Pu Dong, Shanghai China

Discoverer 1980 72 16.4 2 x 480 yes worldwide 2 x 3480 2 x 6000

Discoverer 2 1993 70.1 17.98 3 x 480 yes worldwide 2 x 3480 3 x 6000

Discoverer 6 2013 100 24 12 x 640 yes worldwide 2 x 5800 12 x 8000

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Acq

uis

itio

nca

pabil

ity

Acq

uis

itio

nca

pabil

ity


Seismic

2D

3D

4C

/4D

Shall

ow

transi

tion z

one

Deepw

ate

r

Hig

h d

ensi

ty

Oce

an b

ott

om

ca

ble

Vari

able

depth

Nav

data

QC

data

Full

data

Fin

al

pri

mary

reco

rdin

g m

edia

(typ

e o

r ca

rtri

dge #

)

Sate

llit

e t

ransm

issi

on

to s

hore

(co

mpany

use

d

and t

ransm

issi

on

speed (

baud )

)


x x x x x x x x 3592 256K

x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x x x x 3592 256K

x x x x x 3592 256K

x x x x x x x x 3592 265K

x x x x x x x x 3592 265K







x x x x x x 3590, EHD, USB VSAT

x x x x x x x x 3590, EHD, USB VSAT

x x x x 3590 or EHD

x x x x 3590 or EHD

x x x x 3590 or EHD

x

x x

x x x x Inmarsat C

x Inmarsat C

x x x x Inmarsat C

x x x x Inmarsat C

x x x x 3590 NorSat C

x x Inmarsat C

x x x 3590E Inmarsat C

x x x x x x 3590 64k

x x x x x x x x 3590 64k

x x x x x x x x 3590 64k

x x x x x x 3592 64k

x x x x

x x x x x x 3490E 9.6k

x x x x x x x x 3592, USB VSAT

x x x x x x x 3592 VSAT



qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Bubble

ElectrodeLight

Shockwave

Plasmadischarge



Drillers seek a downhole source

for seismic while drillingSparker technology research effort amps up

In early May, on the eve of the Offshore Technology Conferencein Houston, geoscientists and drilling engineers will gather in Galveston for a workshop on seismic while drilling (SWD) jointly presented by the Society of Petroleum Geologists and the Society of Exploration Geophysicists. The last such meeting

took place in 2007; since then, deeper wells and a post-Macondo em-phasis on well safety have lent new urgency to the effort to develop better methods to see in real time not only what is around the bit during drilling operations, but what lies ahead of it.

SWD systems currently on the market use a surface seismic source and hydrophones deployed downhole in the drillstring to es-timate pore fl uid pressures ahead of the bit. But the surface sourcemethod can slow down the drilling process, and the data gatheredcan be diffi cult to interpret. Over the past several years, researchershave devoted much effort to developing SWD technology that uses a downhole source, based on the assumption that the resulting data would provide much greater resolution. But the efforts so far have

met with little success in tests, says Robert Radtke, president of Technology International. “The primary reason these efforts were not successful is because of tubular losses. In other words, too much of the energy went up along the drillstring and not enough into the

Russell McCulley

Senior Technical Editor

Making a case for SWD offshore

Offshore spoke recently with Neil Kelsall, seismic domain champion, Europe, Caspian and Africa, at Schlumberger, which launched its seismicVISION seismic while drilling service 10years ago. Kelsall discusses the advantages and challenges ofSWD, and where the technology is headed.

Offshore: In what type of offshore applications is SWD most useful?

Kelsall: Seismic while drilling has been best received in deepwater exploration wells and highly deviated development/exploration wells. In exploration wells, especially wildcats, drillers have found it reassuring to receive reliable updates onthe expected target depth, especially if they do not want to drill into it. In the highly deviated/horizontal wells, it is now a routineprocess to acquire data with SWD using no rig time, which would otherwise not be feasible due to the days of rig time or hole stability issues to convey a wireline tool.

Offshore: What are the chief benefits of SWD technology?Kelsall: SWD technology can quickly reduce significant

depth uncertainty, save rig time, and reduce well costs. Itis used to measure seismic velocity to answer operationalproblems in wells where wireline deployment is too risky oris very expensive in terms of rig time. Acquiring the seismic checkshots in real-time mode during the drilling phase givesthe ability to update the driller with the target depth, increasingaccuracy while drilling closer to the target.

In exploration, that means the ± 150-m (500-ft) safety marginto set casing can be reduced to ± 20 m (50 ft). This impacts well design, potentially removing the need for side tracks, contin-

gency casing, and smaller hole sizes.SWD has already played a role in presalt and subsalt plays,

providing real-time prediction of the depth of targets ahead of the bit. Over the last 12 months, we have seen increasing inter-est from operators planning these types of wells.

Offshore: What kind of equipment and procedures areneeded in an offshore SWD program?

Kelsall: We take offshore a seismic air gun array with com-pressed air supply, a small case with programming and clock synchronization system, and the seismic logging-while-drillingtool. For some applications, the gun equipment will be on a boat along with a navigation system to accurately position the seismic source.

In terms of procedures, there is almost no impact on the drilling program, as the measurement is made during pipe con-nection. We ask for the riser boost pump to be shut off whenwe acquire data at the drillpipe connections, and in case of pipe movement caused by rig heave, we may ask for the heavecompensation to be activated to keep the pipe still for a fewminutes.

Walk-above surveys in highly deviated wells involve re-cording data at stationary pipe connections when pulling the drillpipe out of the hole after drilling is complete. The boat captain and navigator keep the guns vertically above the down-hole seismic tool as it moves toward the surface. It is usually possible for the boat to stay in position above the tool without impacting the speed at which the pipe is pulled out of hole.

Offshore: What are the technology challenges involved in SWD?

When a sparker is

activated, a shock wave

radiates from two closely

spaced electrodes

immersed

in fluid.

continued on page 42 ...

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








DEFINING SUBSEA SERVICES

ENVIRONMENTAL DRILLING

BARRIER AVAILABLE FROM CLAXTON

IN A VAST RANGE OF PRESSURE AND

CONNECTION CONFIGURATIONS.

DRILLING RISERS(DRIL-ING RAHY-ZERZ) Leader

With more riser system options than anyone else

and a comprehensive variety of joint connection

options, Claxton is the number one supplier of

drilling risers for sale or rent in the North Sea.

This best-in-class approach to the subsea service

market is just one example of how we're defining,

shaping and leading subsea services.

Learn more about our drilling risers at

www.acteon.com/drillingrisers

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.acteon.com/drillingrisers

Find the answers to your subseapipeline questions in one book!

NOWAVAILABLE!

Industry veterans Andrew Palmer

and Roger King, two of the world’s

most respected authorities in subsea

pipeline engineering, have updated

their defi nitive reference book.

645 Pages/Hardcover/2008

ISBN 978-1-59370-133-8

$179.00 US

Order your copy today!

www.PennWellBooks.com

Master of the Oceans

GVA 40000

GVA IS THE LEADINGPROVIDER OF PRODUCTION SEMI-SUBMERSIBLESGVA designs are based on proprietary Production Semi-submersible technologies. Safety and environmental considerations govern a design process which achieves significantly enhanced operability.

GVA Production Semi-submersibles have excellent motion performance and are designed for harsh operating environments.

K13012 © 2012 GVA, All Rights Reserved

www.gvac.se


Kelsall: In the beginning, the main hurdle for SWD washaving a downhole clock with enough accuracy for boreholeseismic measurements and the ability to survive incredibly harsh drilling environments. Once this was successfully ac-complished, further challenges remained. There is also some difficulty in ensuring that the SWD tool detects seismic signal rather than noise. SWD sometimes operates in an often less-than-ideal environment for acoustic measurements, and thereare challenges for obtaining real-time data that can be pro-cessed downhole without human intervention. For those cases, and when processing for seismic reflection events deeper than the current tool depth, the whole recording needs to be trans-mitted to surface before the next acquisition. This creates some data conditioning and transmission challenges.

Additionally, seismic airgun deployment for offshore and onshore wells is a challenge that can limit the feasibility for SWD.For onshore wells, gun pits are not always feasible or robust enough for a SWD run lasting several days. Offshore rigs may be limited by crane availability for airgun deployment during drilling.

One of the development goals for seismicVISION services is for it to be transparent to the drilling operation such that the driller’s procedures and operating time are the same with or without the tool in the drilling bottomhole assembly (BHA).

Beyond these technology challenges, the main difficulty fora SWD job is the coordination of the complex SWD equipment and the specialized crew for downhole, surface, and navigationequipment, as well as the interpretation, data deliverables, and decision making often taking place in distant and remote loca-tions. Experience is the key to getting this right.

Offshore: Operators have sometimes been slow to embrace SWD. Is that still the case?

Kelsall: The SWD service is experiencing a broad lifecycle. We have seen early adopters who are keen to assess new technology, along with operators with a unique problem for which SWD has provided a solution. There has been steady growth over the last few years, and the technology is beginning to mature, with SWD appearing in increasingly more logging while drilling and direc-tional drilling tenders from a wide range of operators.

I believe that we will continue to see more SWD applications across the globe, especially in deepwater exploration, as opera-tors are keen to reduce the risk exposure and costs on these large projects.

Offshore: Is cost a factor? Or a lack of case studies or cost/benefit analyses?

Kelsall: The cost of the SWD service is usually not an issue as it is much lower than the issue it is run to address – for ex-ample, saving time for high spread rate rigs or remedial actions for drilling risks like side tracks or extra casing strings.

SWD and borehole seismic in general have not been a “onesize fits all” service and need to be considered on a well-by-well basis to ensure the technology can provide a solution tothe problem. In many cases where borehole seismic can help, a wireline deployed tool may make more sense.

There have been many cases where the operator has drilled an exploration well without SWD and would need a compelling reason to justify using it on the next well. It may be that theyhave an established working practice to reduce depth uncer-tainty using the correlation between a combination of surface seismic, basin modeling, LWD logs, synthetic seismogram, mudlogging, and biostratigraphy. If none of these are conclusive, the operator may acquire a single wireline checkshot for the answer.However, SWD can save rig time and cost in such instances.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.PennWellBooks.com

http://www.gvac.se

If you work in the projects, facilities, and construction discipline of the upstream

oil and gas industry, now is the time to join the Society of Petroleum Engineers.

We have developed new products and services focused on your technical and

professional needs, including the new Oil and Gas Facilities magazine.

And, with 104,000+ members around the world,

you will never meet a new challenge alone.

Learn more and join today at www.spe.org/go/Offshore or scan the QR code to get there faster.

We understand.

We are your global work team.

In your world, each new project is a new adventure—

and a new challenge.


formation. The solution is having greatercontrol over the range of frequencies gener-ated at the source.”

Technology International, with supportfrom Apache Corp. and the US Depart-ment of Energy, developed and tested a drillstring-deployable sparker tool that dem-onstrated the feasibility of a source with adjustable frequencies from as low as 2 Hz up to 1,000 Hz. The tool generated pressure waves at frequencies up to 200 Hz that were observed up to 4,500 ft (1,372 m) away fromthe source. The company is now working with an industry consortium to develop a wireline-deployed reverse vertical seismic profi ling (RVSP) tool with extended range and frequencies that can be controlled fromthe surface. “With the advent of variable frequency bandwidth, we can select the optimal frequency for the range required,”Radtke says. “That depends on how deep you are in the hole and how far away your sensors are from your source.

“What we have is a source where we’ve demonstrated that we can generate frequen-cies from 2 Hz to a kilohertz,” he continues. “That source is what’s called a sparker. When operated in water and provided an electrical impulse that discharges across two electrodes, it forms a high pressure

bubble in the water. This bubble creates a fi rst pressure pulse and, several millisec-onds later, another one due to the bubble collapsing. The time between bubble forma-tion and its collapse determines the center of the frequency band generated. So if you take a conventional sparker and put it in wa-ter at depth, the deeper you go, the higher the frequency. We have developed a way to operate a sparker so that we can generate selected frequency bands that are not depth dependant.”

The goal, says Werner Heigl, a senior staff geophysicist at Apache Corp., is “to have an artifi cial source in the drillstring so you do not have to rely on the bit as a sourceof acoustic energy, and you don’t have to have your sensors in the noisy drillstring. The source is designed in such a way that you, one, can operate it in a certain frequen-cy range that does not have much in com-mon with the frequencies of the noise that the drillstring generates, and two, get the frequency low enough so that these waves actually propagate far enough and can be re-corded on the earth’s surface, or in a nearby well, depending on the application.”

Much of the research in SWD since Ma-condo has been driven by safety concerns, Radtke says. The aim is “to be able to pre-

dict pressure ahead of the drill bit, and also to prevent too high of a mud weight, so you don’t fracture the formation with the drilling fl uid. That is a huge cost factor.” The devel-opment of RVSP could also improve the de-tection of salt fl anks and other obstructionsthat are hard to image directly with conven-tional seismic. Current models, Radtke says, “are not accurate. Typically, they can be offby 500 ft in terms of where productive for-mations are that (operators) want to access.” Seismic data from deep wells can resemble a “snow bank,” he says. “What’s important todrillers is getting to the target. So the signifi -cance of imaging ahead of the bit is that they will be able to reach targets with minimal drilling cost and increased safety.”

With backing from the new industry con-sortium, Radtke is working to double the acoustic energy generated by the sparker in order to produce more uniform seismic signals. “Because we operate at low fre-quencies, we don’t need very high power,”he says. “Range is primarily a function of frequency, not power. With our low frequen-cies, as predicted by acoustic modeling, we could conceivably be at the bottom of a 35,000-ft well, bring a signal to the surface,and see 1,000 to 3,000 ft ahead of bit, de-pending on the formation.” �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.spe.org/go/Offshore

80

60

40

20

00 5

Vantage

Seadrill Rowan

EnscoNoble

Diamond

Atwood

Transocean

Herculesy = 1.3754x – 3.2488R2 = 0.5962

10 15 20 25 30 35

Fleet average (years)

Sta

cke

d p

erc

en

tag

e (

%)

Average fleet age and the proportion of the fleet stacked in Dec. 2010.

Source: Data from Jefferies and Company, Inc., 2012.

500,000

450,000

400,000

350,000

300,000

250,000

200,000

150,000

100,000

50,000

01952

Floaters

Jackups

1962

y = 6250.6x – 1E + 07R2 = 0.6444

y = 3044.2x – 6E + 06R2 = 0.6237

1972 1982 1992 2002 2012

Delivery year

Avera

ge d

ayra

te (

$/d

ay)

Delivery year and average dayrates of jackups and floaters from 2000-2010.

Source: Data from RigLogix, 2011.


D R I L L I N G & C O M P L E T I O N

Reviewing newbuild drill rig strategiesData suggests that as contractor size increases,

newbuild investment decreases

Drilling contractors maintain a portfo-lio of rigs specifi c to their business strategy and ability to access capital markets. Generalists maintain a geo-graphically and technically diverse

fl eet, while specialists are smaller fi rmsthat cannot simultaneously compete in all regions and markets, and thus specialize to build customer relationships.

This second of a three-part series de-scribes how fi rms specialize, and examines their newbuild strategies. Constructing a newbuild rig is a high-risk investment, and contractors undertake various strategies to reduce this risk.

Product differentiation

Demand for drilling services varies across geographic regions and water depth, and a diverse fl eet allows contractors to respond to changing industry conditions. A fl eet di-versifi ed by rig type and specifi cation is able to adjust to market upswings and weather industry downturns. High quality and new rigs generally continue to operate (albeit at a lower day rate) during industry downturns. Companies that provide commoditized ser-vices (e.g. shallow water jackups) are ex-posed to greater competitive pressures and lower barriers to entry.

Transocean, Noble, Diamond, and Ensco are generalists active in a large number of

markets and regions, while most other fi rmsspecialize to a greater degree. Seadrill is the only large-cap specialist and focuses on the high-spec markets in the North Sea, South-east Asia, and Brazil. All large-cap drillingcontractors received a majority of their 2011 revenues from the fl oater markets, and de-spite signifi cant jackup fl eets, the fl oatersegment accounted for 85% and 93% of rev-enues for Transocean and Diamond, respec-tively. For Noble, Ensco, and Seadrill, fl oat-ers accounted for approximately 60% to 65% of revenues.

Smaller fi rms such as Hercules, Rowan, Atwood, and Songa are more specialized.Hercules, Rowan, and Songa each special-ize in a single water depth market. Atwood is less specialized and maintains a diverse fl eet; however, most of its revenues are gen-erated by its Asian fl oater fl eet.

Regional concentration

Drilling contractors concentrate assets in regions to capitalize on economies of scale through the reduction of administrative costs, build customer and governmental relation-

ships, and match fl eet and regional character-istics. There are advantages to this approach, but political risk increases with concentration, and to manage this risk, geographic diversity may be a business strategy.

Brazil is a major source of revenue for all fi ve large-cap fi rms, and the US GoM market is a signifi cant source of revenue for almost all fi rms. The North Sea is also an importantsource of revenue for all fi rms. Diamond is particularly dependent on the Brazilian mar-ket. For each fi rm, a single market accounts for approximately half of total revenues.Since the US GoM shallow-water market is in decline and Petrobras has ordered a large number of fl oaters, this strategy may negatively impact these fi rms’ valuations. All other fi rms are more geographically diverse and no region accounts for more than 30% of revenues.

Customer concentration

Due to contractor’s regional concentra-tion, a small number of E&P fi rms frequently make up a large proportion of a contractor’s revenue. This can create risk for the fi rm, be-cause the loss of a single client can eliminate a major source of revenue. Consistent with the importance of the Brazilian market to fi rm revenues, Petrobras is a signifi cant cus-tomer for several fi rms, including Diamond.

National oil companies and majors are

Mark J. Kaiser

Brian F. Snyder

Center for Energy Studies, Louisiana State University

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________________________________





http://www.nov.com/xlsystems/dw

70

60

50

40

30

20

10

0

Standard jackups

Atw

ood

Dia

mon

d

Ens

coH

ercu

les

Nob

le

Row

anSea

drill

Son

gaTr

anso

cean

Vant

age

High-spec jackups

Nu

mb

er

of

rig

s

80

70

60

50

40

30

20

10

0

Standard jackups

Atw

ood

Dia

mon

d

Ens

coH

ercu

les

Nob

le

Row

anSea

drill

Son

gaTr

anso

cean

Vant

age

High-spec jackups

Nu

mb

er

of

rig

s

Inventories of jackup and floater fleetsfor selected firms in 2011.

Source: Financial reports.



the largest customers for nearly all fi rms consistent with their size. Transocean is particularly diverse and its largest customer (BP) only accounts for 10% of revenues. The importance of NOC cus-tomers, including Petrobras, Pemex, and Saudi Aramco, is notable. Given the increasing role state-owned drilling contractors play in the market, these NOCs may shift toward in-house drilling contract services in the future.

Fleet age

Drilling contractors are differentiated by the age of their fl eets. Firms with old fl eets are more likely to stack rigs, while fi rms with young fl eets are more likely to experience high utilization. Hercules depends heavily on United States jackup revenues and the decline in the GoM shallow-water market has led to a high degree of unutilized rigs. Diamond is more diverse with more upgraded rigs in jackup and fl oater markets and broader customer and geographic base.

In an analysis conducted by the authors, all jackups or fl oaters delivered in a given year were grouped together and their day rates averaged over the 2000-2010 period. There was a signifi cant correla-tion between rig age and average day rates, suggesting that fi rms that operate newer rigs are likely to receive higher day rates than fi rms that specialize in older rigs.

Specifi cation and water depth

Transocean, Noble, Ensco, and Diamond are the only drilling con-tractors to own both standard and high-spec jackups and fl oaters. Active and stacked rigs are included in the count, but rigs under con-struction are not. High-specifi cation jackups are defi ned as those ca-pable of drilling in 350 ft (107 m) or greater water depths, or capable of operating in harsh environments. High-specifi cation fl oaters are capable of operating in at least 7,500 ft (2,286 m) of water or in harsh environments. In contrast, all of Seadrill’s units are high-spec, and nearly all of Hercules’ units are standard jackups.

Net revenue by rig class

Net revenue is an important determinant of competitiveness and ability to win work. For Transocean, ultra-deepwater and harsh en-vironment fl oaters are particularly profi table due to high utilization, and a large difference between day rates and operating expense. High-specifi cation jackups were the only market segment with a negative expected net revenue in 2011. Diamond’s deepwater fl eet experienced higher day rates than its ultra-deepwater fl eet, and was Diamond’s most lucrative market. Rigs in the mid-water market gen-erated approximately $40 million per rig for both fi rms, while the jackup segment was only marginally profi table.

Speculative newbuilding

Firms invest in newbuilding when the estimated net cash fl ows from the asset exceed investment criteria and capital budgets and credit markets allow investment. Newbuilding represents a signifi cant capi-tal expenditure, while future day rates and utilization are uncertain. Therefore, newbuilding is a high-risk investment and fi rms undertake strategies to reduce this risk. Three strategies have been traditionally espoused by industry: initial contract, price discount, and speculation. Additionally, in some cases, an E&P fi rm will enter into a joint owner-ship arrangement for a newbuild rig. In the private sector, this is rela-tively rare and is limited to high-risk projects such as Shell’s construc-tion of an Arctic drillship with Frontier Drilling. Among state-owned drilling contractors and NOCs, such arrangements are more common.

Initial contract

Under an initial contract strategy, contractors require an initial long-term contract from an E&P fi rm before investment in order to secure cash fl ows during the early life of the rig. Bob Rose, former

CEO of Global Marine, summarized the strategy in this way: “No newbuilds without a user contract in hand.” Without an initial con-tract, a drilling contractor may experience a negative net cash fl ow in the fi rst years after a rig is delivered, and this can have a signifi -cant negative impact on the profi tability of the investment.

Proponents of an initial contract approach argue that building speculatively provides a signal to E&P fi rms that rig availability will increase in the future, which reduces the motivation of E&P fi rms to commit to long-term contracts. Additionally, building without an initial contract adds supply that is not demanded, which may lead to industry-wide reductions in day rates. Transocean is the largest fi rm in the industry and the most likely to be impacted by fl eet-wide reduction in utilization or day rates. As a result, it is the primary advocate of the initial contract approach.

E&P fi rms are only likely to build against a contract when mar-ket conditions are so tight that they are unsure they will be able to contract capacity. As long as one or more fi rms are willing to build without an initial contract, E&P fi rms will not need to enter into con-struction contracts and initial contracts will be rare. In recent years, independents and majors have rarely entered into initial contracts for newbuilds, but initial contracts are more common for NOCs.

Price discount

Under a price discount strategy, fi rms invest counter-cyclically during periods of low newbuild prices to reduce the magnitude of the risk. Sted-man Garber, former CEO of Sante Fe, summarized the position thusly: “Counter-cyclical is the best time to build, contract or not.” The goal of a price discount strategy is to minimize cost rather than attempt to match supply and demand, and proponents of a price discount strategy argue that the benefi ts of an initial contract do not justify higher capital costs. Lower capital costs allow companies to be more competitive in the long

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








and take the recommendation of ASME, DIN, ISO and

EN into consideration to place a washer underneath the

nut to eliminate galling and great frictional variation…

HERE IS WHAT YOUR HYTORC WILL DO FOR YOU:

* Supreme Safety: You finally operate your HYTORC

without a hazardous reaction arm and backup wrench

and without holding the tool on vertical or inverted

applications

* Top Joint Reliability: You avoid joint-failure and

leakage with precise and even, circumferential joint

compression, which we guaranty

* Top Tool Reliability: You drastically improve your

HYTORC’s longevity and warranty

* Always on Time: You cut the number of passes in half

to avoid delayed startups

* Better Handling: You simplify tool handling to reduce

human error

www.hytorc.com

Being # 1… is no coincidence!

When you own a

2

1

0

-1

-2

-3

-40 2

VantageSeadrill

Aker

Scorpion

Rowan

Northern

Songa

AbanEnsco

Pride

Noble

DiamondDolphin

Atwood

Transocean

Hercules

y = -0.6658x + 3.5043R2 = 0.536

4 6 8 10 12

In (enterprise value)

In (

ca

pex

/EV

)

Relationship between firm size andrelative newbuilding expenditure, 2005-2011.

Source: Data from Jefferies and Company, Inc., 2012.



run because the capital cost is locked in for the life of the rig. While thereis a risk that the rig will be under-utilized after delivery, it is likely that the newbuild rig will be utilized since they are preferred in the market, but at the cost of utilization and day rates elsewhere in the fl eet.

Speculation

During periods of high utilization and day rates, fi rms enter into new-build contracts without an initial contract with the expectation that the rig will win work during the construction period. This is a high-risk strategy because there is a risk that the rig will be unutilized or utilized

at a low day rate after delivery. During newbuild cycles, speculation is the dominant strategy, and since newbuild cycles are the primarysource of fl eet expansion, speculative newbuilding is an important source of new rigs. Price discounting is differentiated from a specula-tive strategy in that proponents of a price discount strategy would not build speculatively during the peak of a newbuild cycle. Thus, price dis-counting is a popular strategy only at the beginning of a newbuild cycle. As of January 2012, 78% of jackups, 65% of semis, and 62% of drillships under construction had been ordered without an initial contract.

Firm size

Firms differ in newbuild strategies, and smaller fi rms spend a larger proportion of their value on newbuilding than larger fi rms.Enterprise value was used to proxy company value, and the fraction of enterprise value invested in newbuild was determined by divid-ing annual newbuild expenditures by total enterprise value over the 2005-2011 period. This value was then plotted against the average enterprise value for each fi rm over the time period.

The data suggest that as the size of the fi rm increased, the pro-portion of fi rm value invested in newbuilding expenditures over 2005-2011 decreased. Over the recent newbuilding cycle, large fi rmssuch as Transocean and Diamond have invested relatively little in newbuilding, while small and mid-sized fi rms such as Scorpion, Van-tage and Seadrill have invested heavily. Instead, Transocean has used cash to fi nance acquisitions which is an alternative strategy to grow and diversify their fl eet, while Diamond typically pays largedividends to shareholders. �

Editor’s note: This article is the second in a three-part series by Mark Kaiser and

Brian Snyder on the offshore contract drilling market.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








http://www.hytorc.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________

_________

_______

_______





http://www.intecsea.com

http://www.offshore.mag.com

http://www.akersolutions.com/subsea

http://www.c-a-m.com/subseasystems

http://www.slb.com/subsea

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________

__________

____ ____ ______





http://www.flowserve.com

http://www.genesisoilandgas.com

http://www.maximizerecovery.com

http://www.siemens.com/energy/subsea

http://www.oceanworks.com



Subsea rotating device

enhances dual gradient drillingNew DGD system undergoes testing prior to deployment in GoM

Dual gradient drilling (DGD) is set to turn the page on a problem that has long challenged the deepwater in-dustry. A new DGD system is being deployed by Chevron and is planned

for deployment in the Gulf of Mexico (GoM) later this year. It will eliminate the weight of thousands of feet of mud in the marine riser system bearing down on the wellbore.

A key component in this system is the in-dustry’s fi rst commercially available subsea rotating device (SRD), which diverts drilling fl uids to establish a dual gradient environ-ment. By diverting mud returns from the well immediately above the BOP, sizing the cuttings, and pumping everything to the sur-face and a specially confi gured rig, the DGD system removes a major constraint to drilling at current depths and points the way to deep-er waters and more challenging reservoirs.

Mud and cuttings in the riser impose a heavy hydrostatic burden in conditions wherenavigating narrow drilling windows between pore pressure and fracture gradient is para-mount. From the perspective of the well, elimi-nating the column of mud extending from the seafl oor to the sea surface and replacing it with a seawater density fl uid effectively plac-es the rig on the seafl oor. As a result, water depth becomes inconsequential in its impact on well design.

This ability of DGD to eliminate riser mud from the downhole hydrostatic equation cre-ates a new operational window for mitigating a host of pressure-related safety, environmental, and operational problems that grow ever moretroublesome with increasing water depth.

With a much-reduced pressure gradient to consider, deepwater operations are able to man-age wellbore pressure and fl uid system design to reduce hole instability and enable the set-ting of deeper casing seats. Fewer problems with wellbore stability reduce non-productive time and improve safety. Deeper seats mean a higher probability of reaching total depth with the designed hole size, and ultimately, a deeper wellbore with a producible hole size. In addition, the return of drilling fl uids to the surface is an environmentally friendly alternative to current techniques that reduce hydrostatic pressure by discharging returns directly to the seafl oor.

DGD defi ned

A conventional drilling system has only one pressure gradient that starts at the sea surface and extends to the bottom of the hole, wherethe full pressure of the entire column of mud is experienced.

The DGD system actively manages two dif-ferent fl uids in the wellbore. One, in the drilling riser, has the density of seawater. The second, from the blowout preventer (BOP) to total depth, has a higher than conventional density.In both conventional and dual gradient drilling, the pressure at the bottom of the wellbore is the same. However, with the DGD fl uid con-fi guration, the pressure profi le created by the two fl uids more closely mirrors what naturehas in place: seawater density next to seawater,and higher density drilling fl uid adjacent to the sediments. The fl uid confi guration underlies the project’s tagline, “working with nature, not against it.”

Note also that this fl uid confi guration can restore riser margin, something not common-

ly seen in deepwater drilling operations. The International Association of Drilling Con-

tractors’ Dual Gradient Drilling Subcommittee defi nes DGD as a subset of managed pressuredrilling used in subsea applications to manage the annular pressure profi le by creating multiple pressure gradients. The advantage this affords has driven decades of thoughtful consideration and concerted industry effort. The effort has yielded a variety of innovative technologies grouped around three primary methods: seabed pumping, dilution, and mid-riser pumping.

GoM system

The newly developed DGD system is cur-rently undergoing system integration testing (SIT) prior to deployment in the GoM, and it fi ts in the seabed-pumping category.

Its development is the latest effort in a long commitment to DGD that began in 1996 and has engaged a wide scope of experts as well as industry consortia. Building on this foun-dation, the new DGD system itself is the cul-

Andrew Barry

Weatherford

With the DGD fluid configuration, the pressure profile created by the two fluids more closely mir-

rors what nature has in place: seawater density next to seawater, and higher density drilling fluid

adjacent to the sediments.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Moody Gardens Hotel & Convention Center

Galveston, TX | November 5-7, 2013

www.deepwateroperations.com

Yesterday’s Experience, Tomorrow’s Innovations and Solutions

The Deepwater Operations Conference and Exhibition will continue the

tradition of excellence in addressing operational challenges involved in

developing deepwater resources. We will return to the Moody Gardens

Hotel and Convention Center on November 5 – 7, 2013 in Galveston, Texas.

Challenges in deepwater production are complex and command our

attention to develop solutions that are economical and long-term.

The Deepwater Operations Conference and Exhibition provides a unique

experience for attendees and exhibitors to share, learn and connect in

a forum dedicated to addressing these challenges.

Save the dates for Deepwater Operations 2013!

Galveston, TX | November 5-7, 2013

Go to www.offshoreoilevents.com to sign up today! Follow us on

owned & produced by: presented by: supported by: Hosted by:

Images courtesy of Anadarko Petroleum Corp.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.offshoreoilevents.com

http://www.deepwateroperations.com



mination of a major engineering effort involv-ing many experts and companies.

Eighty-seven feet tall, it stands above the low-er marine riser package (LMRP) and BOP to form a structure that towers 135 ft (41 m) above the high-pressure wellhead housing on the sea fl oor. It comprises the seafl oor end of the DGD system and integrates several major compo-nents including pumps, a solids processing unit (SPU), and the SRD. At the top it is connected to the marine riser; at the bottom to the LMRP.

The SRD diverts annular return fl uids be-fore they enter the riser. Its design is a highly modifi ed subsea rotating control device (RCD) typically used in other variants of MPD. In this DGD application, it forms an annular seal between the wellbore and the riser that allows running and rotating the drill pipe while divert-ing the fl ow of returns. The other key benefi t to this placement of the SRD is that it allows the operator to near-instantly detect and very quickly react to changes in downhole pressure conditions, offering all of the benefi ts of con-stant bottomhole pressure MPD operations.

Below the SRD seal are drilling mud and cuttings; above the seal in the riser is a light-weight fl uid. It is this isolation of the annular fl uid column into two discrete fl uid compo-nents that eliminates the weight of several thousand feet of drilling mud in the riser that would otherwise put pressure on the well-bore.

The diverted returns enter the SPU, where incoming mud is processed to reduce the size of formation cuttings to no larger than 1.5 in. (3.8 cm), then to the inlet of a company’s gas pump, and pumped to the surface via a conduit system that is integrated into the drilling riser. At the surface, a specially modifi ed rig re-ceives the fl uid and pumps it through the rig’s mud processing system and back down the drill pipe. This highly complex system truly in-vites a “moon-landing” analogy. It represents a huge undertaking involving the collaboration of hundreds of specialists from several compa-nies and the integration of many technologies.

Collaboration reigns

The collaborative development process for the DGD system refl ects a growing need for combined technologies and skills to solve the complex challenges of modern wellbore con-struction. The discrete application of limited so-lutions is too often unable to meet multiple chal-lenges presented by extreme conditions, from safety and environmental concerns to costs and practical construction methods.

This dynamic is clearly seen in the develop-ment of the Chevron DGD system. Its design and engineering entailed a major collabora-tive process of over four years that engaged a group of key providers and many other spe-cialists. Engineers from multiple disciplines and companies worked to integrate a com-

plex array of components and clear a diverse set of hurdles, from handling tools on the rig fl oor to designing a new rig circulating sys-tem, and powering subsea operations.

Training was a signifi cant aspect of this col-laboration. To effi ciently integrate all the com-ponents and subsystems into the engineering process, it was important for the design team to be aware of all the equipment involved and how it worked. In this overall educational ef-fort, each provider also established discrete programs to train team members who inter-faced with their specifi c technology.

Seafl oor rotation

Within the broad scope of the DGD proj-ect, development of the SRD was a narrowly focused task aimed at isolating the two fl uid gradients. The SRD objective was similar in some aspects to other MPD operations, al-though it differed greatly in application.

When Chevron fi rst approached Weather-ford in 2009 about developing a SRD, Weath-erford was operating an API certifi ed subsea RCD that integrates with the marine riser below the tension ring. The RCD, the fi rst of its kind in deepwater operations, provided the basis for the SRD design that would be integrated with the DGD system.

The Model 7875 RCD is typically used as a proactive deepwater well control barrier that enables a range of capabilities in closed loop drilling systems, including early kick detec-tion, riser gas handling, and the application of constant bottomhole pressure and pressurized mud cap MPD variants. While based on this technology, the SRD design is a signifi cant change from the existing Model 7875 RCD. The major difference is its conversion from a hydraulically operated device to a mechanical system. Changing to a mechanical system sim-plifi ed integration of the SRD with the whole package of equipment.

The resulting device embodies all the com-ponentry in the standard bearing assembly for Weatherford’s marine series of RCDs. But instead of the latch mechanism being in the housing, it was added to the bearing assem-bly itself. This facilitates simplifi ed operations because the bearing can be set and released mechanically for maintenance and to provide full bore access through the riser.

The solution relies on a common industry mechanism used with wireline safety valves, locks, and other devices. These devices are run into a nipple profi le in the tubing string and set mechanically. The SRD adopts this technology in its use of seating keys that are run into a riser joint profi le. The bearing as-sembly lands in the profi le and is latched me-chanically with set-down pressure. The run-ning tool is part of the drillstring.

The design of the SRD is the result of a long process of evolving RCD technology. The device that began as a simple diversionary device used on land rigs for air drilling has become synony-mous with a variety of sophisticated closed-loop drilling and MPD applications across a full range of drilling structures, from land rigs to platforms, jackups and fl oaters.

Deeper waters ahead

The deployment of the new DGD system is the industry’s latest effort to resolve a major challenge in deepwater drilling. By dividing the drilling fl uid column into two discrete compo-nents, the system creates a dual gradient envi-ronment that harmonizes the hydrostatic pres-sure contained in the riser and wellbore with the pressure column existing in nature. With this closer alignment, wellbore hydraulics can be more effectively managed, safety and envi-ronmental objectives can be enhanced, and a new subsea world of even deeper prospects can be explored and developed. �

A key component in the new DGD system is the

industry’s first commercially available subsea

rotating device (SRD), which diverts drilling

fluids to establish a dual gradient environment.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








YOU REQUIRE: Successful Deepwater Well Interventions In Challenging Sea Conditions.

WE RESPOND: With Motion Compensating Intervention Or Completion Systems.

You Require. We Respond.

Nature has many ways to challenge offshore well operations: storm systems, tidal waves, and loop currents. Devin International, a division of Greene’s Energy Group, has the proven and trusted answers to effectively deal with those challenges.

When performing well intervention opera-tions in deepwater or harsh environments, Devin’s Motion Compensation Systems —Motion Buster™, DIME™, Dual DIME™, Lift Frames and DALF — provide the coiled tubing support necessary to ensure safe, efficient and accurate operations.

Devin Website: www.DevinDevin.comGreene’s Energy Group Website: www.GreenesEnergy.com

Sixty Years of Service

VISIT BOOTH #904 · ICOTA · MARCH 26-28

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.GreenesEnergy.com

http://www.DevinDevin.com

Gun

Gun

Rack

Guide ram

Rack actuator

Lock actuatorLock actuator

CIRP connector

No go ram


P R O D U C T I O N O P E R AT I O N S

Enhanced coiled tubing improves well

intervention offshore MalaysiaPerforation technique reignites production at Angsi fi eld

The Angsi fi eld has become a signifi -cant priority in terms of oil and gas production for Petronas Carigali Sdn. Bhd., a subsidiary of Malaysia’s na-tional oil company. The fi eld, which

consists of both oil and gas reservoirs and currently has one main platform and four satellite drilling platforms, is in the southernMalay basin in a water depth of about 69 m (226 ft).

Exploration began in 1974, with fi rst oil and gas production in 2001 and 2002, re-spectively.

Well A-33 was drilled and completed in late 2004 with dual 3½-in. oil and gas produc-tion tubing. The well penetrated three payzones, namely the H, I, and J reservoirs.In the early production phase, the well was

producing from H-40 and H-50 via the shortstring while H-60/H70/I-115/J-10/J-20 res-ervoirs were commingled and producedthrough the long string – A-33L.

The long string has low reservoir quality with estimated porosity and water satura-tion of about 24% and 45%, respectively. Theinterval was perforated with a 45⁄8-in. tubing-conveyed perforating gun and was com-

pleted without gravel pack. The string was put onstream in late 2004 and only managed to produce at an initial rate of 20 MMcf/d of gas and about 1,200 b/d of condensate. Gas production rapidly declined to about 5 MMcf/d after two years of production.

In mid-2008, the well ceased productionbecause of low fl ow tubing head pressure. In mid-2009 and 2010, the string was again put onstream to assess its potential. Three well tests were carried out. The average gas rate obtained was less than 5 MMcf/d. Due to its rapid production decline, the decision was made to restore its potential by adding perforations via coiled tubing.

Adding perforations are challenging due to complexities such as on-depth perforation, depth accuracy of coiled tubing, and uncer-tainty of depth correlation prior to detonation.

Well trajectory

Due to A-33L’s high angle, conventional intervention methods such as normal slick-line and electric line were restricted in reaching the target depth. The highest dog-leg severity recorded in this well is 9.4°/100 ft at 1,600 m (5,249 ft) with highest deviation 72° recorded at 2,723 m (8,934 ft). Slickline was able to run in the hole with the assis-tance of a mechanical jar and slickline rollerboogies. However, the tools descended with multiple hold-ups and low running weight.

Subsequently, the option of perforation via electric line conveyed by tractor and coiled tubing was evaluated but would require mul-tiple runs. Considering the length of the per-foration, 120 ft (37 m) across I-95 and I-100 sand, coiled tubing completion insertion and retrieval under pressure (CIRP), which is able to complete the job in a single run, was ultimately selected as the conveyance meth-od for the additional perforation job.

Completion insertion and

retrieval under pressure

Completion insertion and retrieval under pressure is a technique used to deploy long gun strings under pressure when the lubrica-tors are shorter than the entire gun string. It is useful for retrieving long gun strings from a perforated well without killing the well.

Mohd Izwan Abd Jalil

Ooi Zhon Wei

PETRONAS Malaysia

Mohamed Heikal Kasim

Mohd Fakhrurazi Ishak

Schlumberger

Completion equipment

for insertion and retrieval

under pressure.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Get

one

thing

straight

Outstanding output stability, structuralintegrity and ease of use make the E3Modulevel® displacer transmitter a betterlevel control solution than torque tubes.

Avoid the twists and turns of torque tube technology’s performance, durability and maintenance. The E3 Modulevel’s LVDT range spring technology is the straightforward choice for accurate, reliable liquid level measurement and control.

Contact Magnetrol®, the level control experts, for straight talk about E3 Modulevel displacer transmitters.

www. Magnetrol.com

��

�� !

TR

UE

B

LU E RE

LI A

BIL

ITY

E3 Modulevel® Torque TubeOutput Stability

�� !��

�� "��!��#�$�%&��#��#��

Structural Integrity

�� '��(��

�� )��$�$*�� +'��'��#

�� ,��

�� -�� '��(��

�� $�$�� +�� .��!��

��'��

Ease of Use

�� /��0�� #��

�� 1��#��#��2��

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.Magnetrol.com



The system is also used for multiple perforat-ing runs without killing the well between runs, or to overcome wireline weight limitation. CIRP also makes it possible to re-perforate older wells without stopping production, which cuts down production loss and potential formation damage. For this project, the well was still producing.

Safety is a concern, especially when dealing with the live guns on the surface. CIRP provides the added safety value in that when deploying guns under pressure it deploys the fi ring head separately from the gun. The head is installed in the lubricator and is then pressurized before being connected to the gun with CIRP. Acciden-tal activation of the head when being pressur-ized would be harmless, as it is not connected at this time. CIRP allows the perforation in an underbalanced condition in a single run, which not only improves operation time but can also minimize formation damage and improve well cleanup after the perforation.

Fiber optic-enabled

coiled tubing with gamma ray

and casing collar locator

Fiber optic-enabled coiled tubing is a real-time bottomhole mea-surement and communication system that uses live telemetry to read bottomhole measurements. As opposed to the conventional coiled tubing string where job parameters are read from the sur-face, fi ber optic-enabled coiled tubing improves job effi ciency by not having to guess downhole behavior.

The standard application of the fi ber optic-enabled coiled tubing with its bottomhole assembly (BHA) includes downhole pressure inside and outside of the coiled tubing, downhole temperature read-ing, and depth correlation using a casing collar locator (CCL). To increase the accuracy of coiled tubing depth correlation, a gamma ray (GR) module is attached within the standard BHA, which allows close to accurate depth control.

Fiber optic along the coiled tubing string collects point measure-ments downhole and optically transmits the data to surface in real time via the fi bers. The features of the fi ber optic-enabled coiled tub-ing system are:

• Dual-barrier pressure containment with surface and downhole pressure bulkheads

• Minimal impact on pumping operations• Negligible weight increase to coiled tubing reel• Requires only basic slack management• Hardware support for distributed temperature measurements• Wireless data collection, which eliminates the need for a collector. A known disadvantage of conventional coiled tubing is that depth

accuracy is often questionable because of the possibility of no sur-face indication that fi ring has taken place downhole. The introduc-tion of fi ber optic-enabled coiled tubing was necessary to avoid off-depth perforation and getting the live guns back to surface. GR and CCL work in tandem to get the perforating guns at the target depth with great accuracy, while real-time bottomhole pressure and tem-perature confi rm that the perforating guns are fi red as planned.

Chronology of operation

Well A-33L initially experienced high condensate issues. De-scribed below is the summarized chronology of events at the well from the fi rst attempt of well clean out before the insertion of long guns.

First run – coiled tubing fi ll cleanout. The sequence of the clean-

up operation went as follows:• Rigged up CT equipment on the platform• Pull tested the CT connector and pressure

tested the CT string• Made up high-pressure jetting tool and

function tested the tool at the surface• Made up the CT stack-up and pressure

tested the complete CT stack-up• Ran the high-pressure jetting tool to the re-

quired depth• Performed well clean up with seawater fol-

lowed by viscous gel pills• Plugged the jetting nozzle • Replaced the high-pressure jetting tool with

cleanout nozzle• Continued to perform the well cleanup until

plug back to total depth• Pulled CT to surface to prepare for the per-

forating runs.This was the fi rst run into the well where

coiled tubing performed a well cleanup using a high-pressure jet-ting tool and viscous gel pills. Several expected obstructions, such as hard fi lls, were removed with high-pressure jetting before being transported out from the well with the assistance of the viscous gel pills.

However, it was not anticipated that some loose fi lls were present in the casing when the high-pressure jetting nozzle was unexpect-edly plugged as indicated by the inability to go down further dur-ing cleanout. The plan changed after discussions between Schlum-berger and Petronas Carigali: the cleanout nozzle was used for the subsequent run and managed to touch down the plug back to total depth, indicating that the well was cleared prior to running with the perforating guns.

Second run – perforating with fi ber optic-enabled coiled tub-

ing. The sequence of the perforation operation went as follows:• Rigged up CT stack-up to include the CIRP deployment system

and gate valves• Rigged up the surface lines• Pull tested the CT connector and pressure tested the CT string• Assembled and pressure tested the complete CT stack• Broke off the risers’ connection at the quick test sub (QTS)• Made up the deployment BHA and proceeded with the perforat-

ing guns deployment• Made up the QTS after the completion of the perforating guns

deployment and pressure tested the connection• Broke off the QTS connection• Picked up the fi ring head with stinger assembly and secured

into the well stack• Removed the deployment BHA and made up the real-time BHA

before connecting to the fi ring head• Connected the QTS and pressure tested the connection• Performed the last deployment of the fi ring head into the perfo-

rating guns in between the CIRP deployment system• Ran CT into hole for the perforating runs• Performed the correlation with the real-time GR/CCL via fi ber

optic-enabled CT• Confi rmed the perforating depth based on the baseline log pro-

vided• Picked up CT to the top shot with the aid of real-time GR/

CCL reading and activated the fi ring head with the signals that match the commands preset on the surface

Gun strings for 120-ft perforation interval.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








ww

w.p

ola

rcus.c

om

At Polarcus our highly trained geoscientists specialize in survey design and planning. Utilizing some of the latest software modelling tools and a wealth of experience we can help �� the geological objectives, to ensure that you get the most from your data.

Making the RIGHTCHOICES

RIGHTPLAN

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________





http://www.polarcus.com

Use reprints to maximize your marketing initiatives and strengthen your brand’s value.CUSTOM REPRINTS

REPRINTS ARE IDEAL FOR:

■ New Product Announcements ■ Sales Aid For Your Field Force

■ PR Materials & Media Kits ■ Direct Mail Enclosures

■ Customer & Prospect Communications/Presentations

■ Trade Shows/Promotional Events ■ Conferences & Speaking Engagements

■ Recruitment & Training Packages

For additional information, please contact Rhonda Brown at

Foster Printing Service, the official reprint provider for Offshore.

Call Rhonda at 866.879.9144 ext. 194

or [email protected]


• Upon confi rmation of detonation of the perforating guns, pulled CT to the sur-face

• Performed reverse deployment of the spent perforating guns using the CIRP deployment system.

The major challenge of the second runwas to rig up the coiled tubing well control stack with the inclusion of the CIRP deploy-ment system. Two extension frames were used on top of the jacking frame to accom-modate the space required for the CIRP de-ployment with coiled tubing. This resultedin higher than conventional rigless coiled tubing stack up on the platform.

Twenty guns were deployed successfully at a rate of two hours per each gun section.

The most critical step was to correlatethe depth of the gun placements prior to detonating the fi ring head. This is where thegamma ray/casing collar locator live corre-lation via fi ber optic-enabled coiled tubing vastly assisted the decision making in avoid-ing off-depth perforations.

Using the live gamma ray/casing col-lar locator correlation, the guns were posi-tioned across the agreed depth prior to ac-tivating the fi ring head. Pulse signals were sent down the coiled tubing to activate the fi ring head, once the signals matched the

preset signals set on the surface. The per-forating charges fi red into the formationinstantly initiated the additional gas produc-tion expected from the well.

Besides live correlation GR/CCL, the abil-ity to monitor the real-time bottomhole pres-sure and temperature greatly facilitated the fi ring confi rmation of the perforating guns.

Results

The live GR/CCL via optical telemetryinside the fi ber optic-enabled coiled tubing managed to improve on-the-job decision mak-ing before the gun detonations took place. The additional critical data, such as coiled tubing bottomhole pressure, annular bot-tomhole pressure, and bottomhole pressure, proved that a better picture of the overall per-forating operation can be monitored. Follow-ing the operation, an additional 50 MMcf/d of gas began fl owing from Angsi A-33L well.

Conclusion

The application of CIRP via fi ber optic-en-abled coiled tubing with gamma ray and casing collar locator to perforate I-95 and I-100 sands across a 120-ft (36.5-m) interval was proven to be extremely successful. The new perforated zones currently show superior results, with a gas production rate of about 50 MMcf/d after

being idle for almost two years.Risk analysis, technical discussions, and

cost evaluation were critical in the decision making throughout evaluation of the CIRP perforation option. Close monitoring during the operation was also one of the contribut-ing factors in achieving these successful results.

In conclusion, such application is highly recommended for long interval perforationsin highly deviated wells, which cannot be reached by other conventional interventionmethods.

The ability to perform all the long gun deployments in a single run signifi cantly re-duces the operation duration, allowing ear-lier monetization of the production gain. �

AcknowledgmentBased on a paper presented at the SPE Annual Techni-

cal Conference and Exhibition in San Antonio, Texas,

Oct. 8-10, 2012.

References

1. PETRONAS Procedures and Guidelines for

Upstream Activities (PPGUA), revision 2. August

2008. Petroleum Management Unit, PETRONAS.

2. PCSB Well Intervention Standard Operating

Procedure (SOP), revision 1. December 2010.

PETRONAS Carigali Sdn. Bhd.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







INNOVATION MATTERS.DELIVERING RESULTS BEYOND YOUR IMAGINATION.

At Cudd Energy Services, we use unconventional thinking to solve

unconventional challenges. When our client faced a challenge that

required repetitive rig ups and rig downs, we delivered a patent-pending,

coiled tubing solution. CES eliminated costly steps, increased operational

efficiencies and improved personnel safety on the job. The possibilities

are endless with ingenuity and experience.

To learn more, visit us at www.cudd.com today.

PROVEN EXPERIENCE. TRUSTED RESULTS.WWW.CUDD.COM

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________





http://www.cudd.com

http://www.cudd.com


S U B S E A

Novel deepwater riser bundle

is constructed offshore Hybrid system installed by heavy-lift/pipelay vessels

The need for alternatives to steel cate-nary and fl exible risers has increasedwith the need for a larger number of risers in deeper water and on con-gested fi elds. Together with Total and

INTECSEA, Heerema Marine Contractors (HMC) is developing a new riser system that increases the available suite of deep-water riser solutions. It is an offshore con-structed hybrid riser bundle installed using heavy lift and pipelay vessels.

The need to evolve the riser concept range is in large part due to the increasingwater depth, number of conduits, riser di-ameters, and the ability of the various types of production fl oaters to receive the risers. Furthermore, the complexity of the fi eld res-ervoirs increases insulation requirementsfor fl ow assurance, making pipe-in-pipe and heavy wet coating necessary. An importantdevelopment is the successful introductionof bundled riser towers. These are con-structed onshore, then towed and installed on location. A major advantage of these riser towers, apart from the decoupling from the fl oater motions, is reduced congestion on the seabed compared to the alternative of a large number of single risers. In addition, bundling of risers has economic advantages and mitigates the potential clashing of ad-jacent risers or structures. A disadvantage is that they are constructed onshore andtowed to location. This requires a dedicated bundle fabrication site and, depending on the tow distance, impacts the fatigue of the tower.

The novel concept described herein al-lows the construction of a bundled riser tower at the installation site, opening up the applicability of bundled riser towers to a larger (and often deeper water) area. Off-shore construction can result in a simple and robust in-place design that is easier to inspect, and which offers the opportunity to exchange and remove individual risers or the complete tower.

Although the concept is new, it is based on fi eld proven TLP and pipelay technology. Introducing novel technology to the market requires due consideration of the economic viability, robustness, and safety of the sys-

tem. This introduction was supported byTotal through its evaluation qualifi cationprocess, in which key risks and areas areidentifi ed and mitigated and the system is matured to a project-acceptable level.

The concept is considered suffi cientlymatured for a West African application and can be developed further to suit an in-creased payload and/or number of risers for different fi eld applications.

Deepwater riser systems

The free standing production riser system tower, often referred to as a free-standinghybrid riser (FSHR) system, can bundle various functions (production, service, um-bilical, and export) into a single structure between the seabed and the fl oating unit.

The FSHR generally is offset from the fl oating unit using fl exibles and has the top of the tower at a depth of around 100 m (328 ft) to reduce the impact of fl oater motions and wave loads on the tower. This confi gura-tion enhances the application in harsh envi-ronments.

The development of fl oating productionsystems in the 1980s prompted the introduc-tion of free-standing hybrid riser systems. Mobil introduced the fi rst actual free stand-ing application on the Placid Green Canyon fi eld (470 m, or 1,542 ft water depth) in the Gulf of Mexico in 1988. This system was moved to the Ensearch Garden Banks fi eldin 640 m (2,100 ft) water depth in 1994.

In 2001, the onshore-fabricated, towedriser tower, named the hybrid riser tower (HRT), was introduced by Total E&P on the Girassol fi eld in 1,350 m (4,428 ft) wa-ter depth. Similar developments followed on Rosa Lirio (Total, 2007) and Greater Pluto-nio (BP, 2007).

As an alternative to multiple riser towers, the single line offset riser (SLOR) was intro-duced on ExxonMobil’s Kizomba A projectin 1,280 m (4,198 ft) water depth (2004).

Advantages included the use of offshore construction by pipelay vessels and the ability to install in remote areas where atowed option is not feasible. The SLOR re-quires more space on the seabed than does an HRT. Similar developments followed on Kizomba B, P52 (Petrobras, 2007), and Cas-cade Chinook (Petrobras, 2009). The SLOR is also known as single line hybrid riser (SLHR). HMC installed one such system for the block 31 PSVM project where nineSLHRs were installed by the DCV Balder in 2011.

The SLOR concept was further enhancedby the grouped SLOR confi guration, a con-cept that bundles a number of SLORs.

The preferred solution for a specifi c fi eld

Frank Lange

Cor Benard

Heerema Marine Contractors

Hervé de Naurois

Total SA

Edward van Duyvenbode

Epsilon Consultancy Ltd.

Dan Lee

Neil Willis

INTECSEA (UK) Ltd.

Overview of hybrid

exchangeable riser

tower installed.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








O n e C o m p a n y . . . U n l i m i t e d S o l u t i o n sEmail: [email protected]© 2

013

Nat

iona

l Oilw

ell V

arco

All

righ

ts r

eser

ved

D39

2004

997-

MK

T-00

1 R

ev 0

2

NOV Pressure Pumping SolutionsAt NOV, we don’t just piece together a solution that “gets it done.”

From concept to operation, the strengths of trusted brand names

��

of engineering expertise to deliver custom made equipment

�� !�

�� "

#�$%�� &�� '��(��(��

need from a simple expendable to complete pumping packages.

)��(�� (��

�� "�*��+�� !��

operation contact: www.nov.com/wise

— Stimulation Products

— Cementing Equipment

— CT Support Equipment

— Acidizing Equipment

— Liquid Additive Systems (LAS)

— Sand Handling and Transport Systems

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.nov.com/wise

Upstream Standards. Bottom Line Results.

With Energistics’ Standards, you never

have to worry that something will get

lost in translation.

Want to Improve Digital

Oilfield Communications?

Energistics has a

Standard for that.

Open data exchange standards from

Energistics are embedded in more than

40 software packages used by more than

100 oil and gas companies globally.

Does Your Digital Oilfield

have a Language Barrier? S U B S E A

requires the assessment of a number of factors related to other com-ponents in the development. These include the following:

• Riser system costs• Track record and operator experience with the concept• Concept robustness considering inspection and monitoring,

maintenance, repair, and replacement• Field layout and possible congestion• Floater type (spread moored FPSO, turret FPSO, spar, TLP, or

semi)• Number and type of risers and fl ow assurance requirements• Contractor (yard/equipment) availability.An important advantage of the FSHR is the decoupling of fl oater

and riser motions, and the reduction of payload on the fl oater. Forcongested fi elds, SLOR and bundled riser tower are the preferred so-lutions, particularly when it involves an increased number of produc-tion lines with larger (more than 10-in.) diameters in deeper water.

Novel riser concept

The hybrid exchangeable riser tower (HERT) system is based on offshore assembly of pre-fabricated components using heavy-lift and/or pipelay vessels where the core structure is installed fi rst, similar to the installation of TLP tendons. Thereafter, individual riser assem-blies can be installed on the perimeter of the buoyancy tank to create

Evaluation qualifi cation program

Key challenges in innovating for the offshore industry arethe high standards for health, safety, environment, operability,maintainability, and robustness. Total applies an EvaluationQualification process to help ensure fast introduction of novel technology before a development enters the project front-endengineering and design (FEED) phase. The Technology Evalu-ation Qualification is a systematic process with the objective of evaluating new technology and its applicability as well as toenhance its development in an efficient and structured way.

The Evaluation Qualification is a staged process that ad-dresses all aspect of the technology’s functionality and oper-ability over its full life cycle.

The hybrid exchangeable riser tower evaluation is a struc-tured process:

• Phase A assesses the actual performance of the technology• Phase B seeks to understand and characterize the level of

maturity of the technology’s innovative elements or systems• Phase C assesses the risk inherent in the technology, and

estimates and categorizes the severity of risk (called critic-ity); identifies mitigation actions to reduce overall risk toan acceptable or manageable level; and most importantly establishes its manageability, i.e. a level of difficulty to actu-ally implement these mitigation actions

Following this classical analysis, the aim is then to address uncertainties associated with this new technology and its ap-plication to reduce them in a focused way.

• Phase D identifies the root of these uncertainties to allowoptimization of the actual resolution by bringing the neces-sary solutions to the most critical part of the uncertainty. Thisimproves the “technology readiness level” by representative demonstrations, supported by the most fit-for-purpose analysis, testing, or prototypes. Phase D defines the resolutions within the Resolution Management Plan

• Phase E involves evaluation and qualification of the risertower. This required a number of critical elements to be further designed before moving ahead to conventional pre-development design. To support the input for the evaluation qualification, a full concept design for a typical field was done to ensure a consis-tent design and to allow the critical uncertainties and maturity and risk issues to be tackled.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







Reel Sale and Rental

Assembly of M-Reels

DNV Certified ReelsSuitable with all standard drive systems300t / 400t payloadsSize 8.6m – 12.4mFast delivery worldwideFixed prices Mob./Demob.

Construct ASP.O. Box 203, N-4098 Tananger,Norway

Sales @Construct.mr.nowww.Construct.mr.no

Positioning - for success.8 cm accuracy worldwide (2 drms)

High accuracy Heading/Pitch and Roll sensors

GPS, GLONASS and GNSS solutions

QA/QC NMEA outputs compliant with

OGP 373-19 / IMCA S 015

Precise Stable & Reliable

Easy to Install

Angola Brazil Mexico Singapore South Africa United Kingdom USAwww.cnav.com

WORLDDGNSS

S U B S E A

the complete tower.The HERT is composed of the following main elements:A foundation structure. Either a driven pile or suction pile ar-

rangement with a roto-latch connection for connecting the tendon. This component is fi eld proven and has been used on previous riser towers.

A tendon string with attached spacer structures. This compo-nent is novel but is based on TLP tendon connection technology, allowing offshore construction.

The spacers are intended to avoid riser clashes and to reducevortex-induced vibration. They are strategically positioned along the length of the riser at varying distances, but at an average of 130 m (426 ft). They allow connection and disconnection of the risers. The tendons are assembled using Merlin Tension Leg Element (TLE) type connectors with the spacers pre-attached to the tendons as in TLP installation.

A buoyancy tank. The buoy requires considerable payload capac-ity. It carries the weight of the risers, the tendon, including spacers, and part of the fl exible weight. The size of the tank can be adjusted accordingly, and the current buoy concepts with diameters in the range of 10 to 13 m (33 to 43 ft) can accommodate payloads from1,200 to 3,400 metric tons (1,323 to 3,748 tons). The height is gov-erned by the lift height of the cranes given that the tendon string is attached to the buoy at deck level. Although the size and weight of the buoy (on the order of 2,000 metric tons, or 2,205 tons) is consid-erable, they are well within the capabilities of conventional heavy-lift vessels.

A number of riser assemblies. Consists of a riser segment (sin-gle line or pipe-in-pipe) with an upper riser assembly (URA) and a lower riser assembly (LRA). The riser assemblies are hung off at the

perimeter of the buoy. Such assemblies are similar to short fl owlinesegments or to SLORs, for which the fabrication and installation are fi eld proven. A URA provides the connection to the buoy (for weight transfer) and a vertical connector for the top spools. An LRA pro-vides the vertical or horizontal connector to the base spool and hori-zontally fi xes the riser to the tower via a base structure with a sliding mechanism to allow for vertical expansion and stroking of the risers.

A top assembly. Rigid spools are used on the top of the buoy between the URA and the fl exible jumper. These spools are installedafter the fl exible jumpers have been installed and fi xed on the riser balcony.

A connection system for each fl exible jumper. A fl exible balco-ny connects the fl exible jumpers to the buoy structure. The fl exiblejumper is fi rst connected to the buoy and then to the FPSO.

Base spool arrangements. The base spools connect the LRAs with pipeline end terminations (PLETs) on the fl owlines. They have confi gurations similar to previous riser towers and SLORs.

The HERT is installed in the following general sequence:1. Prepare a seabed foundation through a driven pile or the use

of a suction pile2. Construct the tendons (with attached spacers) onboard the in-

stallation vessel3. Connect the buoy to the tendon string and connect this struc-

ture to the foundation4. Build up each riser (including LRA and URA) and lower it on a

crane or winch5. Displace the buoy laterally with a tug, and then connect the

riser to the tower at the LRA. Continue attaching the all risers to the spacers through combined action of tug and crane, and hang off the riser URA on the buoy assembly

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.cnav.com

http://www.Construct.mr.no


S U B S E A

Installation sequence of the riser tower.

6. Lower the base spools and connect the LRAs with the PLETs 7. Once the FPSO has arrived, the fl exible jumpers can be connected 8. Connect the top spools between URA and porches for the fl ex-

ible jumpers9. Pre-commission the total system.Key aspects of the novel riser tower technology are:• Equal functionality compared to “traditional” HRT• Open tower structure with improved inspectability and, if re-

quired, replaceability• Exchangeability of individual risers or addition of additional ris-

ers for phased fi eld developments and/or fl ow assurance con-siderations

• Application in remote areas not limited by (bundle wet tow) distance to shore

• Limited fatigue damage to the risers during installation (by avoiding the tow and upending phases)

• All main components can be fabricated locally onshore but the method also allows for competitive bidding from several inter-national yards as the system is assembled offshore

• Installation of the buoy structure can be a separate phase from the riser installation which optimizes schedule options.

Concept design

The concept design of the HERT system for West African applica-tion was based on the following:

1. Water depth at the FPSO of 1,712 m (5,615 ft)2. Two 12-in./16-in. P-I-P production risers with gas lift through

the pipe-in-pipe annulus3. Two 14-in. water injection (WI) risers4. Two 12-in. service line (SL) risers5. Total riser payload (fl ooded) 2,135 metric tons (2,353 tons)6. High thermal performance7. Remote intervention/maintenance by ROV

8. Diverless installation9. 25-year design life. The system was jointly designed

by HMC and INTECSEA using static analysis, response analysis, computa-tional fl uid dynamic (CFD) analysis, fatigue analysis of risers and tendon including fi rst and second order, VIV and vortex induced motion (VIM) fatigue, installation and removal de-sign, and design of spacer frame, base structure, URA, LRA, buoyancy tank, top and base spools, and more.

Key aspects were the riser and ten-don stress responses and the fatigue performance given the novel appli-cation of the spacers. The response analysis under extreme storm con-ditions showed that the von Mises stress on all the risers and tendon was within the allowable range.

First and second order fatigue analy-ses were carried out and the results showed that the fatigue damage due to second order vessel motions were mini-mal. Overall, a minimum factored fatigue life of more than 39 years was achieved for the HERT system, which exceeds the design life target of 25 years.

Fatigue damage assessment of VIV was carried out for the risers and ten-

don. The results show that the factored life obtained is of the order of 60 years for the risers and 100 years for the tendon, assuming a conservative VIV fatigue factor of 15. It should be noted that VIV suppression devices (e.g. strakes) are only required for the service line and water injection risers in order to meet the design life re-quirement.

Resulting characteristics of the designed tower are:• Total sum of risers submerged weight (fl ooded) 2,200 metric

tons (2,425 tons)• Buoyancy tank weight 1,675 metric tons (1,843 tons)• Tendon submerged weight (including spacers, etc.) 335 metric

tons (369 tons)• Maximum lift weight tendon string and buoyancy tank 2,400

metric tons (2,646 tons).

Future development

During conceptual design, the HERT was found to offer a number of options for adjustment to other fi eld conditions such as deeper water and a larger number of risers. The size of the buoy is limited at present by the ability to connect the buoy above water, but it is also possible to connect the buoy submerged, allowing for a longer buoy length. An increased payload can then be achieved by fi xing additional buoys to the submerged buoy. �

References

1) Lessons learned from the evolution and development of multiple-lines hybrid riser

towers for Deepwater production applications; V. Alliot and J.-L. Legras, Stolt

Offshore SA; OTC 17683, 2005 Houston.

2) The Greater Plutonio Riser Tower; Daniel de la Cruz and Charles Zimmermann,

BP, and Pierre Neveux and Frank Louvety, Acergy; OTC 19929, 2009, Houston.

3) The Evolution of Freestanding Risers; Elizabeth Tellier, Ricky Thethi, 2H Off-

shore Inc.; OMAE2009-79487, Hawaii.

4) Qualifi cation of the Grouped SLOR Riser system; Daniel Karunakaran, Dan Lee

and John Mair, Subsea 7; OTC 19899, 2009, Houston.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








��

��

�� !� ��"��#��#$%"&'(#%$��

��

)�� )�"�!�� )�*��+�*��

)�*�� )� �� )�'�� )��

��)��,-./��0�1��2�� )��2��"��3��)��4.5-/��)��5667//7�"��#��)��,,/78.67,9:9��)��;�,,/78.67,9::

��'��<�� =�� 0��'��<�� "�� 0��'��

$��

�< �� '3��

�� >� � ��

"� ��?��

2��7��

'3��

��

@��

��

'��3��

%��?��

��

��

#1 Magnetic Level Indicator

#1 Magnetostrictive Level Transmitter

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________





http://www.orioninstruments.com


S U B S E A

Subsea processing comes of ageIndustry now offers a diverse array of power transmission solutions

The offshore oil and gas industry was pi-oneered by risk takers and innovative thinkers. The boundaries of possibility have been and continue to be pushed further from shore and into deeper

water. With these advances have come in-creased challenges, but also increased risks, in magnitude and severity of consequence. In turn, the industry has responded with an ev-er-increasing emphasis on system integrity.

In today’s market, innovations which have matured through industry-accepted technol-ogy readiness level evaluations must then confront a risk-adverse culture where fewcompanies put up their hands to be serial number 01. However, those few companies do exist and the industry continues to push forward, as evidenced by the growth and de-velopment of the subsea processing market.

Currently, subsea processing projects can be found in nearly every major offshore oil and gas region in the world, with the North Sea and offshore Brazil (Campos and Espirito Santo basins) experiencing the most activity to

date. While still an emerging market, with the number of installed systems relatively small (about 30), recognition of the potential returns, and hence the level of acceptance of subsea processing technologies, continues to increase. Subsea processing is now appearing in develop-ment options for many industry projects.

Subsea processing defi ned

Subsea processing is the application of hydro-carbon processing equipment at the seafl oor.Traditionally, these seafl oor systems comprised subsea separation, boosting, and gas compres-sion equipment, as well as the associated en-abling components for electrical power transmis-sion, distribution, and subsea controls. The most mature of these technologies is subsea boosting,

followed by separation and compression.The use of subsea boosting has increased

fairly steadily with increasing power and wa-ter depth. These trends can be seen with the upcoming commissioning of Jack/St. Malo (Chevron) and the Julia (ExxonMobil) fi elds, both in the Gulf of Mexico. Subsea separation is expected to proliferate due to its impact on high water-cut production, common in aging reservoirs. Subsea separation has a mixed history, including the recent notable success of the Total Pazfl or system operating offshoreWest Africa. Major subsea gas compression projects, particularly Ormen Lange, Asgard, and Gullfaks, are in their fi nal development stages and their outcomes will signifi cantly impact future developments.

Subsea processing rewards

The application of subsea processing equip-ment spans the operational life cycle, from greenfi eld to brownfi eld developments, with the ultimate goal of increasing recoverable reserves through more effective fi eld man-

Mac McKee

Larry Forster

John Allen

Richard Voight

INTECSEA

Overview of subsea power transmission options. For further details, see

the Subsea Boosting and Processing poster contained in this issue.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Offshore Technology Conference6–9 May ❖ Houston, Texas, USA

www.otcnet.org/2013

Attend the offshore energy industry’s

premier, global event!

OTC gives you access to

leading-edge technical

information, the industry’s

largest equipment

exhibition, and valuable

new professional contacts.

Register now to attend!

S U B S E A

agement. These technologies have the potential to convert marginal fi elds into economically viable developments; to overcome deepwater and environmental challenges, such as fl ow assurance; and to extend the production life of a mature reservoir. Additionally, the reduction in size, or possibly the elimination altogether of the otherwise required topside facility can signifi cantly reduce both capex and opex, thus mak-ing subsea processing a high-value investment.

While an increase in overall recovery is the primary reward of sub-sea processing, there are inherent benefi ts associated with the develop-ment and implementation of new technologies. This atmosphere fos-ters increased competition, which in turn drives innovation.

Electrical power transmission

This year’s Subsea Boosting and Processing poster, developed by INTECSEA and published by Offshore, has a new section with a special focus on subsea power transmission. This section shows the maturity and the diversity of power solutions now emerging.

Supplying and managing electrical power to subsea processing sys-tems has been recognized as a signifi cant challenge. But these same challenges – the distances involved, the power levels, and the economies of scale – have resulted in a wider array of equipment types. Addition-ally, each type of equipment represents a signifi cant investment as well as (most likely) a particular installation challenge.

As subsea processing matures, methods for delivering power to these installations are becoming clearer, common equipment types arebeginning to take shape, and systems-level considerations are becom-ing even more apparent. Distinct categories of power delivery systems are also beginning to emerge, all tailored to delivering increasing levels of power over longer distances in subsea environments.

There are a number of factors to consider when reviewing power sup-

ply options for subsea processing systems. For moderate power and rela-tively short distances from the host facility, conventional 50/60 Hz AC can suffi ce. As distances and power levels increase, other options such as low frequency AC can be advantageous. For relatively high power and long-distance applications (as seen on Ormen Lange), signifi cantly high-er AC voltages may be employed. Complexities with the use of AC power have also led to the consideration of high voltage DC, which is currently undergoing research for anticipated future applications.

Looking to the future

With state-of-the-art technologies being implemented or pro-posed, and many other solutions being considered or tested, it is clear that the subsea processing market remains one of the most innovative within the offshore industry.

The industry is, however, still in the midst of establishing reliable data for subsea processing technologies. As this data is collected and used to improve upon currently available equipment, the application of subsea processing will continue to be driven in the near term by the industry’s risk-takers. Few can doubt that the future of subsea process-ing looks remarkably promising, especially as developments become more challenging and operators drive for increased overall recovery.

Subsea processing poster

This issue of Offshore contains the 2013 Worldwide Survey of Subsea Processing Systems, the sixth installment of this industry resource. This survey is on the Subsea Boosting and Processing poster. The pri-mary aims of this poster are to chronicle the development and develop-ers of these systems, and to document the continued commitment of oil companies to the application of these technologies. For online access to view and download, visit www.offshore-mag.com/maps-posters. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.otcnet.org/2013

http://www.offshore-mag.com/maps-posters

2 Ways to Register for the Webcast:1. Register at http://bit.ly/BPWebcastSeries2. Register by scanning the QR code below

WEBCASTR E G I S T E R N O W

BP Upstream – Insider Insights Webcast Series

What You Will Learn:

BP’s Insider Insights Webcast Series will focus on BP’s revitalized Upstream division. Exposing the new operating structure, revealing the technology leadership and working culture, and highlighting BP’s 15 major projects starting up by 2014.

• Wednesday 20th March: An introduction to a revitalized BP Upstream and our Global Projects Organization

• Wednesday 3rd April: An insight into Engineering & Quality at BP

• Wednesday 17th April: An insight into my career at BP and the delivery of major projects

Who Should Attend:

• Asset & Project Engineers & Managers

• Deepwater/Subsea Engineers & Managers

• Construction/Commissioning Engineers & Managers

• Projects and Discipline Engineers & Managers

• Quality and HSSE Engineers & Managers

Guest Speakers:

March 20, 2013 | 9:00 am CDT | 2:00 pm GMTApril 3, 2013 | 9:00 am CDT | 2:00 pm GMTApril 17, 2013 | 9:00 am CDT | 2:00 pm GMT

Ryan Malone

Delivery Mgr,Hull & Mooring

Systems, GPO —Mad Dog

Phase 2 Project

March 20th April 3rd April 17th

Ian CumminsVP Engineering &

Quality, GPO

Rob KellyVP Technical

Functions, GPO

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://bit.ly/BPWebcastSeries

OCTOBER 22-24, 2013THE WOODLANDS WATERWAY MARRIOTT HOTEL & CONVENTION CENTER

HOUSTON, TX USA

www.deepoffshoretechnology.com

OWNED & OPERATED BY: PRESENTED BY:

SUPPORTED BY: HOSTED BY:

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.deepoffshoretechnology.com

The Advisory Board of DOT International — the leading global conference & exhibition for deepwater and

ultra deepwater exploration and production — invites you to submit an abstract and share your knowledge,

experience, and ideas with leading technological experts and strategic decision-makers.

The conference topics for DOT 2013 refl ect the industry’s increasing demand for new technology and

services to safely and effi ciently grow the global reserves base from the world’s most prolifi c, and

prospective, resource play — deepwater.

CALL FOR ABSTRACTSThe Advisory Board of DOT International — the leading global conference & exhibition for deep and

ultra-deepwater exploration and production — is now accepting paper abstracts for the 2013 Conference.

We invite you to submit an abstract and share your knowledge, experience and ideas with

technical and strategic decision-makers and strategists.

This conference is a great opportunity to network with leading organizations and high level infl uencers

and for you to represent your company at the most prestigious event for the industry.

WHO WILL BE YOUR AUDIENCE?Oil & Gas industry professionals, experts and managers, including:

• Industry leaders who seek information and technologies for future operations

• Senior decision makers from international and regional operators

• Oil and gas operating companies

• Service and equipment suppliers

• Engineering and construction companies

• Contractors

• Consultants

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







• Safety and Environmental Management

System (SEMS)

• Drilling Safety

• Subsalt Drilling & Completion

• Managed Pressure Drilling

• Seismic Advances

• Dual-Gradient Drilling

• Heavy-Lift Technology

• Floating Production Facilities

• Lessons Learned - Field Development

• Brownfi eld Development

• Multi-Field Development

• Lessons Learned in Deepwater Operations

• Marginal Field Development

& Maximization

• Production Optimization

• Field Architecture & Development Concepts

• Technology Qualifi cation and

Implementation

• Subsea Technology

• Subsea Boosting & Processing

• Long Distance Subsea Tiebacks

• Risers & Riser Technology

• Arctic Technology

• Flow Assurance

• Flowlines & Pipelines

• Well Construction / Drilling Technology

• HP/HT Drilling & Completion

• Completion Design in Deepwater

• Subsea Intervention

• Mooring & Station-Keeping

• Advanced Materials

• Construction / Installation

• Risk & Reliability

• Technology Development Initiatives

• Project Execution & Management

• Workforce Resource Issues

• HSE

• Gas Development

• Floating LNG

• Model Testing & Response Prediction

• Subsea Well Intervention

• Oil Spill Recovery & Containment

• Emergency Response Technology

• Project Financing

• Regulatory Compliance

• Geology & Geophysics

• Training & Development

• Asset Integrity

• Reservoir Monitoring & Control

• Pipeline Installation

• Enhanced Oil Recovery

• Subsea Increased Oil Recovery

• Decommissioning

• Production Operations

• Downhole Monitoring & Control

• Reservoir Simulation

• Geotechnical Challenges & Solutions

• Regional Challenges & Trends

• Trends in Deepwater Exploration

& Production

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________________________________






SHOULD YOU WISH TO SUBMIT AN ABSTRACT

FOR CONSIDERATION, PLEASE FOLLOW THE

PROCEDURES BELOW.

All abstracts must be submitted using the on-line form found on the DOT

International web site: www.deepoffshoretechnology.com

The main body of your abstract should be between 150 and 300 words.

For full guidelines and requirements, please visit the DOT International website:

www.deepoffshoretechnology.com under the conference section.

STEP-BY-STEP PROCEDURE:

• go to www.deepoffshoretechnology.com

• click on “submit abstract” in the left navigation bar

• complete the required fi elds

• press submit

• relax, your abstract has been submitted!

Please submit your abstract ONLY ONCE and wait for the automatic

e-mail confi rmation.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM










NIKI VRETTOSCONFERENCE MANAGER

T: +44 (0) 1992 656 630

F: +44 (0) 1992 656 700

E: [email protected]

ANNICOLE FAETHMARKETING MANAGER

T: +1 918 832 9347

F: +1 918 832 9274

E: [email protected]

DESIREE REYESAMERICAS

T: +1 713 963 6283

F: +1 713 963 6212


JANE BAILEYEUROPE, MIDDLE EAST & AFRICA

T: +44 (0) 1992 656 651

F: +44 (0) 1992 656 700


MIKE TWISSSE ASIA, AUSTRALIA, NEW ZEALAND

T: +61 8 9529 4466

F: +61 8 9529 4488


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







B U S I N E S S B R I E F S


People

Chad Deaton will retire as chairman of

Baker Hughes Inc. on April 25, 2013, at the

company’s annual meeting. Martin Craighead

will become chairman in addition to his cur-

rent role as president and CEO.

Marathon Oil Corp. has appointed Michael

J. Stover as vice president,

operations services.

Calidus Engineering Ltd.

has appointed Brian Green

as managing director.

BP has named Bob Fryar

executive vice president for

safety and operational risk.

IHC Asia Pacifi c has

appointed Francis Tang

as product director for the Product Market

Combination team, which is responsible for

global sales and marketing of service and

support vessels.

Phil Kirk has joined the board of directors

of Oil & Gas UK.

Unitech has appointed Martin Vahl as

CEO.

Newfi eld Exploration has appointed Rich-

ard K. Stoneburner to its board of directors.

W. Kirk Brassfi eld has resigned as senior

vice president and CFO of Parker Drilling.

Philippe Varin has stepped down after

almost seven years as a non-executive director

of BG Group.

Sophie Zurquiyah has joined CGG as

senior executive vice president of the geology,

geophysics, and reservoir division.

Stork Technical Services has appointed Ste-

ven Law as HSSEQ director – UK and Africa.

ROVOP has appointed Moray Melhuish

as commercial director and Mike Duffus as

project manager.

Glacier Energy Services has appointed

Mark Derry as managing director of the

offshore division, and George Leggate as

managing director of the

engineering division.

UTEC has appointed

Simon Hird as general

manager of its Australian en-

tity UTEC Survey Australia

Pty Ltd.

Tony Duncan has joined

McDermott International as

vice president and general

manager, subsea.

Topsides,

Platforms & Hulls

In its third year, Topsides, Platforms & Hulls attracted more than 1,500 attendees and 109 exhibitors. Held Feb. 5-7 in Galveston, Texas, the advisory board helped put together a strong program of operator presentations with two tracks – one for Topsides and one for Platforms and Hulls. Advisory board chairman George Gu presented Le-

ong Wong of Chevron with the best presentation award, and Andre Barrios of Shell with the best presenter award. This annual event will return to Galveston, Feb. 4-6, 2014.

Back row standing: Ken Caldwell, Foster Wheeler Upstream; David Brubaker, Shell Upstream Americas; William Taggart, Murphy E&P; Russell McCulley,

Offshore; Tad Mulder, Cameron; Jonathan Brewer, Stress Engineering Services; Randy Bush, Woodside Energy USA Inc; James Britch, Hess Corp.; James

Voskamp, WorleyParsons; Mike McEvilly, Hess Corp. Front row sitting: Stafford Menard, Williams Midstream; Wendy Buskop, The Buskop Law Group; Jose

Vazquez, Bennett & Associates; Maarten van Strien, Eni Petroleum; Advisory Board Chairman George Gu, ConocoPhillips; Riley Goldsmith, Goldsmith En-

gineering; Conference Manager Gail Killough, PennWell; Alec Johnson, Petrobras America Inc; Chris Sherertz, KBR Inc. Not pictured: James Deaver, BHP

Billiton; Rendard Falcon, Chevron; Murray Burns, Technip; Bruce LeGros, McDermott; and Eric Wensel, Mustang Engineering.

(Right) Advisory board chairman George Gu presented Leong

Wong of Chevron with the best presentation award, and

(far right) Andre Barrios of Shell with the best presenter award.

Green Hird

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








B U S I N E S S B R I E F S


Wentworth has appointed Gerold Fong as vice president explora-

tion. He will lead the company’s geology and geophysics reviews,

analyses, and interpretations.

Tony Antoniou has joined Mentor Australia as director project

management services, and Mark Wood has joined as a senior resource

consultant.

Specialist Services Group has appointed Derrick Reith as managing

director of its UK business Labtech Services Ltd. in Aberdeen.

BP has appointed Michael Townshend as senior vice president -

Russia BP Group.

Hyperdynamics Corp. has elected Ian Norbury to

its board of directors.

Paul Clasper & Associates Ltd. has named Rich-

ard Edwards technical director.

The Underwater Centre has appointed James

Ridgeway as training operations manager at the Fort

William facility.

Jamie Oag has been appointed CEO of Aberdeen-

based SPEX Group, the group behind the develop-

ment of Shell’s latest drilling tools for well closure

and severance.

UniversalPegasus International has named Wel-

lington Banks manager of GeoPlane Services, and

has promoted Max Hengst to vice president of com-

mercial and marketing.

David Grenier has joined Spectraseis as sales di-

rector in Houston, and Richard Marcinew has joined

as an engineering adviser based in the company’s

Calgary offi ce.

Jee Ltd. has appointed Mike Hawkins as technical

director and head of the London offi ce, and Graham Wilson as team

leader and lead engineer.

TWMA has appointed Leif Ove Svensen as Scan-

dinavia region manager.

Environmental Drilling Solutions has appointed

Richard A. Pattarozzi to its board of directors.

COSCO Corp. has appointed Ouyang Chaomei as

alternate director of Wang Yu Hang and a member

of the Enterprise Risk Management Committee. He

replaces Liu De Tian.

William T. Heller IV and Harry R. Beaudry

have joined Mayer Brown fi rm as partners in its

Corporate & Securities practice in Houston.

Dan Dorran has been named vice president seis-

mic in order to develop Atlas Copco Rental business

in the seismic applications market.

Saipem has appointed Giuseppe Caselli as COO

of the engineering and construction business unit.

CSL has appointed Sean Girvan as managing

director.

HB Rentals has promoted Glenn Aguilar to senior

vice president of global operations, and Norman

Porter to director – Eastern Hemisphere.

UTEC has appointed Jamie Laing as general man-

ager in Aberdeen, Scotland, and Andrew Stenson as

general manager in Naples, Italy.

Dave Bodecott has resigned as a board of direc-

tor of Rockhopper Exploration.

Aquatic Engineering & Construction Ltd. has

appointed Martyn Conroy as business development

manager, Europe, Middle East, and Africa.

The International Marine Contractors Association

has appointed Massimo Fontolan as president and chairman of the

association’s Overall Management Committee.

Erik Sarmento Staubo has joined Star Information Systems as

head of oil and gas.

Company News

Helix Energy Solutions Group has completed the sale of Energy

Resource Technology GOM, the company’s oil and gas subsidiary,

to Talos Production LLC. Proceeds from the transaction were about

$620 million in cash, as well as overriding royalty interests in ERT’s

successful Wang discovery and certain exploration prospects.

Cameron has announced an agreement with China National Pe-

troleum Corp. (CNPC) to establish a joint venture for the manufacture

of pipeline ball valves. Under the agreement, Cameron will license its

technology to the joint venture and establish a full-scale manufacturing

operation in Tianjin, China, with CNPC Bohai Equipment Manufactur-

ing Co. Ltd.

Wilhelmsen Technical Solutions has established a new offi ce in

Houston.

CNR International, Expro, and FMC Technologies have joined

ITF, the technology facilitator for the global oil and gas industry.

ABB has agreed to acquire APS Technology Group, a San Diego,

California-based company that develops and markets solutions for the

port industry. The acquisition will expand ABB’s crane system portfolio

to the container terminal market. APS will join ABB’s Process Automa-

tion division.

Forum Energy Technologies Inc. has rebranded its DPS Offshore

product line as Forum Subsea Rentals.

Benthic Singapore has received OHSAS 18001 and ISO 9001:2008

certifi cations.

Offshore Middle East

Manzoor Roome, Texas A&M University, Qatar, was the winner of the inaugural Shell-sponsored Student Paper Program at the Offshore Middle East Conference & Exhibition, Jan. 21-23, 2013, in Doha, Qatar. Roome’s paper addressed the protection of offshore operations from cyber-threats by improved SCADA security.

From left to right: Mubarak A. AL-Hajri, Operations Manager - Offshore

Fields, Qatar Petroleum; Wael Sawan, Managing Director and Chairman,

Qatar Shell Companies; Manzoor Roome; HE Dr. Mohammad bin Saleh

AL-Sada, Minister of Energy & Industry and Chairman and Managing

Director, Qatar Petroleum; and David Paganie, Conference Director,

Offshore Middle East.

Correction: In the article “OGX ramping up activity offshore Brazil” that appeared in the January 2013 issue, Off-shore reported the Parnaiba basin is off the coast of Maran-hão, northern Brazil. The basin is onshore. We regret the error.

Edwards

Heller IV

Banks

Beaudry

Aguilar

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








17th Edition Conference & Exhibition

19-21 March 2013International Conference Centre, Accra, Ghana

www.offshorewestafrica.com

Presented by:Owned & Produced by: Supporting Publication: Under Patronage From Republic of

Ghana, Ministry of Energy

DEEPWATER DISCOVERIES

EMERGINGOPPORTUNITIES

INVITATION TO ATTENDThe 17th annual Offshore West Africa Conference & Exhibition will be

held in Accra, Ghana at the International Conference Centre on 19-21

March 2013.

Offshore West Africa is the premier technical forum focused exclusively

on West African offshore exploration and production. The annual

Offshore West Africa Conference and Exhibition remains the leading

source of information on new technology and operating expertise for

��

offshore Africa deepwater technology event in the world.

What Offshore West Africa offers:�� !��

engineers from major and independent E&P companies focusing on

��

�� "�� "��

��

improvements in African E&P operations

�� #��

with the expanding African exploration & production activity

REGISTER ONLINE NOW AT WWW.OFFSHOREWESTAFRICA.COM

Follow Offshore Events on:

INVITATION TO ATTENDREGISTER TODAY TO ATTEND THE PREMIER EVENT DEDICATED TO THE WEST AFRICAN OIL & GAS INDUSTRY

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_______________________________________





http://www.offshorewestafrica.com

http://www.offshorewestafrica.com

PENNWELL PETROLEUM GROUP

1455 West Loop South, Suite 400, Houston, TX 77027 PHONE +1 713 621 9720 • FAX +1 713 963 6228

David Davis (Worldwide Sales Manager) [email protected]

Mitch Duffy (Regional Sales Manager)[email protected]

Grace Jordan (Classified Sales) [email protected]

GREATER HOUSTON AREA, TX

David Davis [email protected]

USA • CANADA

Mitch Duffy [email protected]

WASHINGTON • OREGON • CALIFORNIA

Mary Sumner [email protected]

UNITED KINGDOM • SCANDINAVIA •

THE NETHERLANDS

9 Tarragon Rd.Maidstone, Kent, United Kingdom ME16 OUR

PHONE +44 1622 721222 • FAX +44 1622 721333 Roger Kingswell [email protected]

FRANCE • BELGIUM • PORTUGAL •

SPAIN • SOUTH SWITZERLAND • MONACO

• NORTH AFRICA

Prominter8 allée des Hérons, 78400 Chatou, France

PHONE +33 (0) 1 3071 1119 • FAX +33 (0) 1 3071 1119Daniel Bernard [email protected]

GERMANY • NORTH SWITZERLAND •

AUSTRIA • EASTERN EUROPE •

RUSSIA • FORMER SOVIET UNION • BALTIC

• EURASIA

Sicking Industrial Marketing, Kurt-Schumacher-Str. 16 59872 Freienohl, Germany

PHONE +49 (0) 2903 3385 70 • FAX +49 (0) 2903 3385 82 Andreas Sicking [email protected]

ITALY

SILVERA MEDIAREPViale Monza, 24 - 20127 Milano, Italy

PHONE +39 (02) 28 46716 • FAX +39 (02) 28 93849 Ferruccio Silvera [email protected]

BRAZIL / SOUTH AMERICA

Smartpublishing Ltd/ OGJLA Pennwell BrazilHEADQUARTERS: Rua Raimundo Chaves 2182, L5

Natal RN 59064-390, BRAZILRIO OFFICE: Ave. Erasmo Braga 227, 11th fl oor

Rio de Janeiro RJ 20024-900, BRAZILPHONE +55 (21) 2533 5703 or +55 (21) 3084 5384

FAX +55 (21) 2533 4593Jean-Paul Prates [email protected]

JAPAN

ICS Convention Design, Inc. 6F Chiyoda Bldg., 1-5-18 Sarugakucho

Chiyoda-Ku, Tokyo 101-8449, Japan PHONE +81 3 3219 3641 • FAX +81 3 3219 3628Manami Konishi [email protected]

SINGAPORE

19 Tanglin Road #05-20 Tanglin Shopping Center Singapore 247909

PHONE +65 9616 8080 • FAX +65 6734 0655 Michael Yee [email protected]

INDIA

Interads Ltd., A-113, Shivalik, New Delhi 110 017 PHONE +91 11 628 3018 • FAX +91 11 622 8928

Rajan Sharma [email protected]

NIGERIA/WEST AFRICA

Flat 8, 3rd fl oor (Oluwatobi House) 71 Allen Ave, Ikeja, Lagos, Nigeria

PHONE +234 805 687 2630 or +234 802 223 2864 Dele Olaoye [email protected]

SALES OFFICES A

Acteon Group ....................................41www.acteon.com/drillingrisers

Aker Solutions .................................. 11www.akersolutions.com/subsea

ASME / UH OTC Crawfish Boil .........10

Avondale ..............................................9www.hii-avondale.com

B

Baker Hughes Incorporated .............21www.bakerhughes.com

Bluebeam Software, Inc. ..................31www.bluebeam.com

Bredero Shaw .................................. 2-3brederoshaw.com

BWA Water Additives ........................16www.wateradditives.com

C

C&C Technologies ............................61www.cnav.com

Cameron ............................................13www.c-a-m.com

CGG ...................................................29cgg.com

Construct AS .....................................61www.Construct.mr.no

Cudd Energy Services .....................57www.cudd.com

D

Devin International ...........................51www.DevinDevin.com

Dril-Quip ..............................................1www.dril-quip.com

E

Energistics ........................................60www.energistics.org

F

FMC Technologies ...........................C4www.fmctechnologies.com

Frank Mohn Flatøy AS ......................23www.Framo.com

G

Ghana National PetroleumCorporation ......................................C3

www.gnpcghana.comGVA Consultants AB ........................42

www.gvac.se

H

HYTORC.............................................47www.hytorc.com

K

Karmsund Maritime OffshoreSupply ................................................17

www.kamos.no

M

Magnetrol International ....................53www.magnetrol.com

M-I SWACO .......................................C2www.miswaco.com/rhadiant

N

National Oilwell Varco. ......................25www.nov.com/sks-series

National Oilwell Varco. ......................45www.nov.com/xlsystems/dw

National Oilwell Varco. ......................59www.nov.com/wise

O

Oceanic Marine Contractors ............27www.oceanicmc.com

Offshore TechnologyConference ....................................... 65

www.otcnet.org/2013Orion Instruments ........................... 63

www.orioninstruments.com

P

PennWellDeep Offshore Technology

Conference & Exhibition ........67-71www.deepoffshoretechnology.comDeepwater Operations

Conference & Exhibition ............ 49www.deepwateroperations.com

Offshore Group ..................... 56, 66www.offshore-mag.com

Offshore West Africa Conference& Exhibition ..............74

www.offshorewestafrica.com PennWell Books .......................... 42

www.PennWellBooks.comPOLARCUS DMCC ........................... 55

www.polarcus.com

S

Sandvik ..............................................19www.smt.sandvik.com

Sembcorp Marine .............................15www.sembcorpmarine.com.sg

Sercel ...................................................5www.sercel.com

SPE ....................................................43www.spe.org/go/Offshore

W

Weatherford .....................................6, 7weatherford.com

The index of page numbers is providedas a service. The publisher does not as-sume any liability for error or omission.

ADVERTISERS INDEX

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







This page refl ects viewpoints on the political, economic, cultural, technological, and environmental issues that shape the future of the petroleum industry. Offshore

Magazine invites you to share your thoughts. Email your Beyond the Horizon manuscript to David Paganie at [email protected].


B E Y O N D T H E H O R I Z O N

Investing in R&D is essential for the offshore industry because technology is the enabler that changes the face of operations and moves the industry into frontier areas. With the offshore industry constantly innovating and developing new technologies that will al-low E&P activities to move into previously uncharted territory, it is important for new concepts to be evaluated and validated.

Validation is an important part of the process of introducing a new technology. When it is completed and a concept is approved, offi -cial acceptance means the plans, reports, or documents have been reviewed for compliance with one or more of the required rules,guides, standards, or other criteria. In a case where there are no defi ned rules or guides specifi cally applicable to a novel concept, it is the role of a classifi cation society to identify the most appropriatecriteria in existing guidelines. And when guidelines do not exist, one of the roles of the class society is to develop them.

It is critically important to evaluate principal safety considerations and potential hazards when new concepts are introduced.

Approval in Principle (AIP) is a process in which a statement is is-sued affi rming that a proposed novel concept design complies with the intent of the rules and appropriate codes. At the AIP stage, risk is assessed on a high level through qualitative techniques.

From a practical standpoint, the fi rst step is to understand the new concept. Once the concept is understood, it is important to iden-tify “novel” areas of the design that go beyond anything previouslybuilt or beyond anything envisaged in the existing rules and other published requirements.

Next, engineers identify hazards so they can establish that, as a minimum, the same overall level of safety contained in existing rulesor in other standards is achieved. They then seek existing rule re-quirements that are most applicable to the identifi ed hazards in the novel concept and use those rules to evaluate the new idea.

The next step is to fi nd equivalent areas of the design that can be evaluated with a certain degree of fl exibility using existing rules,standards, and codes. For areas of the design for which no stan-dards exist but for which the classifi cation society deems indepen-dent evaluation to be prudent, the class society develops new stan-dards based on experience as well as expert input from industry and academia to help guide the effort. Finally, engineering fi rst prin-ciples are applied to certain areas of the design that can be evaluated only in this manner.

Engineering within the AIP process progresses to the point of

demonstrating that likely failure modes and consequences have been identifi ed and have been considered in the concept design. At that point, the need for proof or model testing and data gathering is identifi ed as is any further need for refi ned risk assessment or engineering analysis.

The value in this process is that it provides a consistent approachto evaluation so that all new technology concepts follow the same validation before they can be granted AIP. When AIP is granted, it confers approval on behalf of the class society that a concept appears to be capable of further development in accordance with established standards and sound engineering principles.

Companies that are just beginning to explore the possibilities of a new technology or concept often approach a classifi cation society to get an educated and informed third-party perspective. The value of gaining AIP from a class society is that a company that is introduc-ing a new technology can produce a document issued by an unbi-ased entity attesting to the acceptability of the concept at that stage of development for pursuing and achieving classifi cation.

When AIP has been granted, the company is better equipped to move into the next phases of the project, which involve detailed de-sign, advanced risk assessment, and testing identifi ed in the con-ceptual phase. At this point, the traditional class society role takes the form of design review and survey, ultimately resulting in Class approval. Generally, Maintenance of Class is performed in the tra-ditional sense as well, with periodic surveys carried out to validate renewal of the Class Certifi cate, although for a novel concept, Main-tenance of Class might require a modifi ed or expanded survey fre-quency or scope as a condition of Class until the concept has built up satisfactory service experience in the fi eld.

As offshore operations expand into more exacting environments,technologies will continue to be developed to contend with demand-ing new operating conditions. Because it is essential for novel tech-nologies to be validated before they move into mainstream opera-tions, AIP is a valuable step in the process.

R&D will undoubtedly keep extending the boundaries of what is possible in offshore operations. And AIP will continue to play a central role in helping the industry move safely into these new and technically challenging frontiers.

William J. Sember

Vice President, Global Gas Development, ABS

AIP helps industry

break technology barriers

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________________





http://www.gnpcghana.com

Optimize. Accelerate.

Maximize.For the life of the field.

www.fmctechnologies.com

Copyright © FMC Technologies, Inc. All Rights Reserved.

FMC Technologies delivers complete life cycle

support to optimize the operations of subsea

fields. Our boosting and monitoring technologies

accelerate production. And our subsea processing

and intervention services maximize recovery in the

most difficult subsea reservoirs. Wherever the field,

whatever the challenge, we’re with you every day,

in every way. For the life of the field.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







http://www.fmctechnologies.com

OM Mar 2013

Documents